Dominion Energy Gas 10-K 28 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Feb. 15, 2019	Jun. 30, 2018
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Trading Symbol	D
Entity Registrant Name	DOMINION ENERGY INC /VA/
Entity Central Index Key	715,957
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		799,313,999
Entity Public Float			$ 44,400,000,000
Virginia Electric and Power Company
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
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 Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		274,723
Entity Public Float			0
Dominion Energy Gas Holdings, LLC
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Entity Registrant Name	Dominion Energy Gas Holdings, LLC
Entity Central Index Key	1,603,291
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		799,314,079
Entity Public Float			$ 0

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating revenue	[1]	$ 13,366	$ 12,586	$ 11,737
Operating Expenses
Electric fuel and other energy-related purchases		2,814	2,301	2,333
Purchased electric capacity		122	6	99
Purchased gas		645	701	459
Other operations and maintenance		3,458	3,200	3,279
Depreciation and amortization		2,000	1,905	1,559
Other taxes		703	668	596
Impairment of assets and related charges		403	15	4
Gains on sales of assets		(380)	(147)	(40)
Total operating expenses		9,765	8,649	8,289
Income from operations		3,601	3,937	3,448
Earnings from equity method investee		197	(18)	111
Other income	[1]	1,021	358	429
Interest and related charges		1,493	1,205	1,010
Income from operations before income tax expense		3,129	3,090	2,867
Income tax expense		580	(30)	655
Net Income Including Noncontrolling Interests		2,549	3,120	2,212
Noncontrolling Interests		102	121	89
Net Income		$ 2,447	$ 2,999	$ 2,123
Earnings Per Common Share
Net income attributable to Dominion Energy-Basic		$ 3.74	$ 4.72	$ 3.44
Net income attributable to Dominion Energy-Diluted		$ 3.74	$ 4.72	$ 3.44
Virginia Electric and Power Company
Operating revenue	[2]	$ 7,619	$ 7,556	$ 7,588
Operating Expenses
Electric fuel and other energy-related purchases	[2]	2,318	1,909	1,973
Purchased electric capacity		122	6	99
Affiliated suppliers		305	309	310
Other		1,371	1,169	1,547
Depreciation and amortization		1,132	1,141	1,025
Other taxes		300	290	284
Total operating expenses		5,548	4,824	5,238
Income from operations		2,071	2,732	2,350
Other income		22	76	56
Interest and related charges	[2]	511	494	461
Income from operations before income tax expense		1,582	2,314	1,945
Income tax expense		300	774	727
Net Income		1,282	1,540	1,218
Dominion Energy Gas Holdings, LLC
Operating revenue	[3]	1,940	1,814	1,638
Operating Expenses
Purchased gas	[3]	40	132	109
Other energy-related purchases		135	21	12
Affiliated suppliers		94	87	81
Other	[3]	665	578	514
Depreciation and amortization		244	227	204
Other taxes		200	185	170
Impairment of assets and related charges		346	16
Gains on sales of assets		(119)	(70)	(45)
Total operating expenses		1,605	1,176	1,045
Income from operations		335	638	593
Earnings from equity method investee		24	21	21
Other income		133	104	87
Interest and related charges	[3]	105	97	94
Income from operations before income tax expense		387	666	607
Income tax expense		86	51	215
Net Income		$ 301	$ 615	$ 392
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net income including noncontrolling interests	$ 2,549	$ 3,120	$ 2,212
Net income	2,447	2,999	2,123
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	30	8	55
Changes in unrealized net gains (losses) on investment securities, net of tax	(18)	215	93
Changes in net unrecognized pension and other postretirement benefit (costs), net of tax	(215)	(69)	(319)
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities, net of tax	102	(29)	(159)
Net realized (gains) losses on investment securities, net of tax	5	(37)	(28)
Net pension and other postretirement benefit costs, net of tax	78	50	34
Changes in other comprehensive gains (losses) from equity method investees, net of tax	1	3	(1)
Total other comprehensive income (loss)	(17)	141	(325)
Comprehensive income including noncontrolling interests	2,532	3,261	1,887
Comprehensive income attributable to noncontrolling interests	103	122	89
Comprehensive income	2,429	3,139	1,798
Virginia Electric and Power Company
Net income	1,282	1,540	1,218
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	1	(5)	(2)
Changes in unrealized net gains (losses) on investment securities, net of tax		24	11
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities, net of tax	1	1	1
Net realized (gains) losses on investment securities, net of tax		(4)	(4)
Total other comprehensive income (loss)	2	16	6
Comprehensive income	1,284	1,556	1,224
Dominion Energy Gas Holdings, LLC
Net income	301	615	392
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities, net of tax	(17)	5	(16)
Changes in net unrecognized pension and other postretirement benefit (costs), net of tax	(52)	20	(20)
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities, net of tax	20	(4)	9
Net pension and other postretirement benefit costs, net of tax	4	4	3
Total other comprehensive income (loss)	(45)	25	(24)
Comprehensive income	$ 256	$ 640	$ 368

Consolidated Statements of Co_2

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net deferred gains (losses) on derivative-hedging activities, tax	$ (10)	$ (3)	$ (37)
Changes in unrealized net gains (losses) on investment securities, tax	5	(121)	(53)
Changes in net unrecognized pension and other postretirement benefit costs, tax	75	32	189
Net derivative (gains) losses on derivative-hedging activities, tax	(35)	18	100
Net realized (gains) losses on investment securities, tax	(2)	21	15
Net pension and other postretirement benefit costs, tax	(21)	(32)	(22)
Changes in other comprehensive income (loss) from equity method investees, tax	(1)	(2)
Virginia Electric and Power Company
Net deferred gains (losses) on derivative-hedging activities, tax	(1)	3	1
Changes in unrealized net gains (losses) on investment securities, tax		(16)	(7)
Net realized (gains) losses on investment securities, tax		3	2
Dominion Energy Gas Holdings, LLC
Net deferred gains (losses) on derivative-hedging activities, tax	6	(3)	10
Changes in net unrecognized pension and other postretirement benefit costs, tax	20	(8)	14
Net derivative (gains) losses on derivative-hedging activities, tax	(7)	3	(6)
Net pension and other postretirement benefit costs, tax	$ (2)	$ (2)	$ (2)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents		$ 268	$ 120
Customer receivables (less allowance for doubtful accounts)		1,749	1,660
Other receivables (less allowance for doubtful accounts)	[1]	331	126
Inventories
Materials and supplies		1,039	1,049
Fossil fuel		287	328
Gas stored		92	100
Prepayments		265	260
Regulatory assets		496	294
Other		634	397
Total current assets		5,161	4,334
Investments
Nuclear decommissioning trust funds		4,938	5,093
Investment in equity method affiliates		1,278	1,544
Other		344	327
Total investments		6,560	6,964
Property, Plant and Equipment
Property, plant and equipment		76,578	74,823
Accumulated depreciation, depletion and amortization		(22,018)	(21,065)
Total property, plant and equipment, net		54,560	53,758
Deferred Charges and Other Assets
Goodwill	[2]	6,410	6,405
Pension and other postretirement benefit assets		1,279	1,378
Intangible assets, net		670	685
Regulatory assets		2,676	2,480
Other		598	581
Total deferred charges and other assets		11,633	11,529
Total assets		77,914	76,585
Current Liabilities
Securities due within one year		3,624	3,078
Credit facility borrowings	[3]	73
Short-term debt		334	3,298
Accounts payable		914	875
Accrued interest, payroll and taxes		836	848
Regulatory liabilities	[4]	356	193
Other		1,866	1,537
Total current liabilities		7,647	9,636
Long-Term Debt
Long-term debt		26,328	25,588
Junior subordinated notes		3,430	3,981
Remarketable subordinated notes		1,386	1,379
Total long-term debt		31,144	30,948
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		5,116	4,523
Regulatory liabilities		6,840	6,916
Asset retirement obligations		2,250	2,169
Pension and other postretirement benefit liability		2,328	2,160
Other	[1]	541	863
Total deferred credits and other liabilities		17,075	16,631
Total liabilities		55,866	57,215
Commitments and Contingencies (see Note 22)
Common Shareholder's Equity
Common stock - no par	[5]	12,588	9,865
Retained earnings		9,219	7,936
Accumulated other comprehensive income (loss)		(1,700)	(659)
Total common shareholder's equity		20,107	17,142
Noncontrolling interests		1,941	2,228
Total equity		22,048	19,370
Total liabilities and equity		77,914	76,585
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents		29	14
Customer receivables (less allowance for doubtful accounts)		999	951
Other receivables (less allowance for doubtful accounts)		76	64
Affiliated receivables		101	3
Inventories
Materials and supplies		550	531
Fossil fuel		287	319
Prepayments		28	27
Regulatory assets		424	205
Other	[6]	77	110
Total current assets		2,571	2,224
Investments
Nuclear decommissioning trust funds		2,369	2,399
Other		3	3
Total investments		2,372	2,402
Property, Plant and Equipment
Property, plant and equipment		44,524	42,329
Accumulated depreciation, depletion and amortization		(14,003)	(13,277)
Total property, plant and equipment, net		30,521	29,052
Deferred Charges and Other Assets
Pension and other postretirement benefit assets	[6]	254	199
Intangible assets, net		250	233
Regulatory assets		737	810
Other	[6]	175	219
Total deferred charges and other assets		1,416	1,461
Total assets		36,880	35,139
Current Liabilities
Securities due within one year		350	850
Short-term debt		314	542
Accounts payable		339	361
Payables to affiliates		209	125
Affiliated current borrowings		224	33
Accrued interest, payroll and taxes		248	256
Asset retirement obligations		245	216
Regulatory liabilities		299	127
Other	[6]	587	410
Total current liabilities		2,815	2,920
Long-Term Debt
Long-Term Debt		11,321	10,496
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		3,017	2,728
Regulatory liabilities		4,647	4,760
Asset retirement obligations		1,200	1,149
Pension and other postretirement benefit liability	[6]	632	505
Other		201	357
Total deferred credits and other liabilities		9,697	9,499
Total liabilities		23,833	22,915
Commitments and Contingencies (see Note 22)
Common Shareholder's Equity
Common stock - no par	[7]	5,738	5,738
Other paid-in capital		1,113	1,113
Retained earnings		6,208	5,311
Accumulated other comprehensive income (loss)		(12)	62
Total common shareholder's equity		13,047	12,224
Total equity		13,047	12,224
Total liabilities and equity		36,880	35,139
Dominion Energy Gas Holdings, LLC
Current Assets
Cash and cash equivalents		10	4
Customer receivables (less allowance for doubtful accounts)	[8]	309	297
Other receivables (less allowance for doubtful accounts)	[8]	17	15
Affiliated receivables		10	10
Inventories
Materials and supplies		53	55
Gas stored		12	9
Prepayments		116	112
Regulatory assets	[9]	29	26
Gas imbalances	[8]	162	46
Other	[8]	58	52
Total current assets		747	600
Investments
Investment in equity method affiliates		91	95
Total investments		93	97
Property, Plant and Equipment
Property, plant and equipment		11,238	11,173
Accumulated depreciation, depletion and amortization		(2,971)	(3,018)
Total property, plant and equipment, net		8,267	8,155
Deferred Charges and Other Assets
Goodwill	[2]	547	542
Pension and other postretirement benefit assets	[8]	1,775	1,828
Intangible assets, net		109	109
Regulatory assets		727	511
Other	[8]	86	98
Total deferred charges and other assets		3,244	3,088
Total assets		12,351	11,940
Current Liabilities
Securities due within one year		449
Short-term debt		10	629
Accounts payable		196	193
Payables to affiliates		65	62
Affiliated current borrowings		218	18
Accrued interest, payroll and taxes		265	250
Regulatory liabilities	[4]	21	38
Other	[8]	198	189
Total current liabilities		1,401	1,341
Long-Term Debt
Long-Term Debt		3,609	3,570
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		1,465	1,454
Regulatory liabilities		1,285	1,227
Other	[8]	194	185
Total deferred credits and other liabilities		2,944	2,866
Total liabilities		7,954	7,777
Commitments and Contingencies (see Note 22)
Common Shareholder's Equity
Membership interests		4,566	4,261
Accumulated other comprehensive income (loss)		(169)	(98)
Total equity		4,397	4,163
Total equity		4,397	4,163
Total liabilities and equity		$ 12,351	$ 11,940
[1]	See Note 9 for amounts attributable to related parties.
[2]	Goodwill amounts do not contain any accumulated impairment losses.
[3]	In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy's Consolidated Balance Sheets at December 31, 2018.
[4]	Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas' Consolidated Balance Sheets.
[5]	1 billion shares authorized; 681 million shares and 645 million shares outstanding at December 31, 2018 and 2017, respectively.
[6]	See Note 24 for amounts attributable to affiliates.
[7]	500,000 shares authorized; 274,723 shares outstanding at December 31, 2018 and 2017.
[8]	See Note 24 for amounts attributable to related parties.
[9]	Current regulatory assets are presented in other current assets in Dominion Energy Gas' Consolidated Balance Sheets.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Customer receivables, allowance for doubtful accounts		$ 14	$ 17
Other receivables, allowance for doubtful accounts	[1]	$ 4	$ 2
Common stock, shares authorized		1,000,000,000	1,000,000,000
Common stock, shares outstanding		681,000,000	645,000,000
Virginia Electric and Power Company
Customer receivables, allowance for doubtful accounts		$ 9	$ 10
Other receivables, allowance for doubtful accounts		$ 3	$ 1
Common stock, shares authorized		500,000	500,000
Common stock, shares outstanding		274,723	274,723
Dominion Energy Gas Holdings, LLC
Customer receivables, allowance for doubtful accounts	[2]	$ 1	$ 1
Other receivables, allowance for doubtful accounts	[2]	$ 2	$ 1
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to related parties.

Consolidated Statements of Equi

Consolidated Statements of Equity - USD ($) shares in Millions, $ in Millions		Total	Sun Edison Inc	NRG Energy, Inc	Virginia Electric and Power Company	Dominion Energy Gas Holdings, LLC	Common Units	Convertible Preferred Units	Common Stock	Common StockVirginia Electric and Power Company	Retained Earnings	Retained EarningsVirginia Electric and Power Company	Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss)Virginia Electric and Power Company	Accumulated Other Comprehensive Income (Loss)Dominion Energy Gas Holdings, LLC	Total Common Shareholders' Equity	Noncontrolling Interests	Noncontrolling InterestsSun Edison Inc	Noncontrolling InterestsNRG Energy, Inc	Noncontrolling InterestsCommon Units	Noncontrolling InterestsConvertible Preferred Units	Other Paid-In CapitalVirginia Electric and Power Company	Member UnitsDominion Energy Gas Holdings, LLC
Beginning balance at Dec. 31, 2015		$ 13,602			$ 10,641	$ 3,318			$ 6,680	$ 5,738	$ 6,458	$ 3,750	$ (474)	$ 40	$ (99)	$ 12,664	$ 938					$ 1,113	$ 3,417
Beginning balance (in shares) at Dec. 31, 2015									596	275
Net income including noncontrolling interests		2,212									2,123					2,123	89
Net income attributable to Dominion		2,123			$ 1,218	392						1,218											392
Sale of interest in merchant solar projects		139							$ 22							22	117
Contributions to Four Brothers and Three Cedars			$ 189															$ 189
Distributions						(150)																	(150)
Purchase of Dominion Energy Midstream common units		(17)							(3)							(3)	(14)
Issuance of common stock		2,152							$ 2,152							2,152
Issuance of common stock (in shares)					0				32
Sale of Dominion Energy Midstream common units - net of offering costs							$ 482	$ 490												$ 482	$ 490
Stock awards (net of change in unearned compensation)		14							$ 14							14
Present value of stock purchase contract payments related to RSNs	[1]	(191)							(191)							(191)
Tax effect of Dominion Energy Questar Pipeline contribution to Dominion Energy Midstream		(116)							(116)							(116)
Dividends and distributions		(1,789)									(1,727)					(1,727)	(62)
Other comprehensive income (loss), net of tax		(325)			$ 6	(24)							(325)	6	(24)	(325)
Other		(2)							(8)							(8)	6
Ending balance at Dec. 31, 2016		16,840			11,865	3,536			$ 8,550	$ 5,738	6,854	4,968	(799)	46	(123)	14,605	2,235					1,113	3,659
Ending Balance (in shares) at Dec. 31, 2016									628	275
Net income including noncontrolling interests		3,120									2,999					2,999	121
Net income attributable to Dominion		2,999			$ 1,540	615						1,540											615
Contributions to Four Brothers and Three Cedars				$ 9															$ 9
Distributions						(15)																	(15)
Issuance of common stock		1,302							$ 1,302							1,302
Issuance of common stock (in shares)					0				17
Sale of Dominion Energy Midstream common units - net of offering costs							$ 18													$ 18
Stock awards (net of change in unearned compensation)		22							$ 22							22
Dividends and distributions		(2,087)			$ (1,199)						(1,931)	(1,199)				(1,931)	(156)
Other comprehensive income (loss), net of tax		141			16	25							140	16	25	140	1
Other		5			2	2			(9)		14	2				5							2
Ending balance at Dec. 31, 2017		19,370			12,224	4,163			$ 9,865	$ 5,738	7,936	5,311	(659)	62	(98)	17,142	2,228					1,113	4,261
Ending Balance (in shares) at Dec. 31, 2017									645	275
Cumulative-effect of changes in accounting principles		6			3	3			$ (127)		1,029	79	(1,023)	(76)	(26)	(121)	127						29
Net income including noncontrolling interests		2,549									2,447					2,447	102
Net income attributable to Dominion		2,447			$ 1,282	301						1,282											301
Distributions						(25)																	(25)
Issuance of common stock		2,461							$ 2,461							2,461
Issuance of common stock (in shares)					0				36
Sale of Dominion Energy Midstream common units - net of offering costs		4															4
Remeasurement of noncontrolling interest in Dominion Energy Midstream									$ 375							375	(375)
Stock awards (net of change in unearned compensation)		22							22							22
Dividends and distributions		(2,331)			$ (464)						(2,185)	(464)				(2,185)	(146)
Other comprehensive income (loss), net of tax		(17)			2	(45)							(18)	2	(45)	(18)	1
Other		(16)							(8)		(8)					(16)
Ending balance at Dec. 31, 2018		$ 22,048			$ 13,047	$ 4,397			$ 12,588	$ 5,738	$ 9,219	$ 6,208	$ (1,700)	$ (12)	$ (169)	$ 20,107	$ 1,941					$ 1,113	$ 4,566
Ending Balance (in shares) at Dec. 31, 2018									681	275
[1]	See Note 17 for further information.

Consolidated Statements of Eq_2

Consolidated Statements of Equity (Parenthetical) - $ / shares	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Stockholders' Equity [Abstract]
Dividends declared per common share	$ 0.835	$ 0.835	$ 0.835	$ 0.835	$ 0.770	$ 0.770	$ 0.755	$ 0.755	$ 3.34	$ 3.035	$ 2.80

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Activities
Net income including noncontrolling interests		$ 2,549	$ 3,120	$ 2,212
Net income		2,447	2,999	2,123
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		2,280	2,202	1,849
Deferred income taxes and investment tax credits		517	(3)	725
Current income tax for Dominion Energy Questar Pipeline contribution to Dominion Energy Midstream				(212)
Proceeds from assignment of rental portfolio			91
Contribution to pension plan			(75)
Gains on sales of assets and equity method investments		(1,006)	(148)	(50)
Provision for rate credits to electric utility customers		77
Charges associated with equity method investments			158
Charges associated with future ash pond and landfill closure costs		81		197
Impairment of assets and related charges		395	15	4
Net (gains) losses on nuclear decommissioning trusts funds and other investments		102	(117)	(96)
Other adjustments		19	33	8
Changes in:
Accounts receivable		(110)	(103)	(286)
Inventories		(29)	15	1
Deferred fuel and purchased gas costs, net		(247)	(71)	54
Prepayments		(51)	(62)	21
Accounts payable		67	(89)	97
Accrued interest, payroll and taxes		(12)	64	203
Margin deposit assets and liabilities			(10)	(66)
Net realized and unrealized changes related to derivative activities		181	44	(335)
Asset retirement obligations		(35)	(94)	(61)
Pension and other postretirement benefits		(114)	(177)	(152)
Other operating assets and liabilities		109	(291)	38
Net cash provided by operating activities		4,773	4,502	4,151
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(4,254)	(5,504)	(6,085)
Acquisition of Dominion Energy Questar, net of cash acquired				(4,381)
Acquisition of solar development projects		(151)	(405)	(40)
Proceeds from sales of securities		1,804	1,831	1,422
Purchases of securities		(1,894)	(1,940)	(1,504)
Proceeds from the sale of certain retail energy marketing assets		54	68
Proceeds from sales of certain merchant generation facilities and equity method investments		2,379
Proceeds from assignment of shale development rights		109	70	10
Contributions to equity method affiliates		(428)	(370)	(198)
Distributions from equity method affiliates		36	275	2
Other		(13)	33	83
Net cash used in investing activities		(2,358)	(5,942)	(10,691)
Financing Activities
Issuance (repayment) of short-term debt, net		(2,964)	143	(654)
Issuance of short-term notes		1,450		1,200
Repayment and repurchase of short-term notes		(1,450)	(250)	(1,800)
Issuance and remarketing of long-term debt		6,362	3,880	7,722
Repayment and repurchase of long-term debt		(5,682)	(1,572)	(1,610)
Credit facility borrowings		73
Net proceeds from issuance of Dominion Energy Midstream common units		4	18	482
Net proceeds from issuance of Dominion Energy Midstream preferred units				490
Proceeds from sale of interest in merchant solar projects				117
Contributions from NRG and SunEdison to Four Brothers and Three Cedars			9	189
Issuance of common stock		2,461	1,302	2,152
Common dividend payments		(2,185)	(1,931)	(1,727)
Other		(278)	(296)	(331)
Net cash provided by (used in) financing activities		(2,209)	1,303	6,230
Increase (decrease) in cash, restricted cash and equivalents		206	(137)	(310)
Cash, restricted cash and equivalents at beginning of year		185	322	632
Cash, restricted cash and equivalents at end of year		391	185	322
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		1,362	1,083	905
Income taxes		89	9	145
Significant noncash investing and financing activities:
Accrued capital expenditures	[1],[2]	307	343	427
Receivables from sales of assets and equity method investments	[1],[2]	159
Guarantee provided by equity method affiliate	[1],[2]		30
Virginia Electric and Power Company
Operating Activities
Net income		1,282	1,540	1,218
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		1,309	1,333	1,210
Deferred income taxes and investment tax credits		224	269	469
Proceeds from assignment of rental portfolio			91
Charges associated with future ash pond and landfill closure costs		81		197
Provision for rate credits to customers		77
Other adjustments		(21)	(36)	(16)
Changes in:
Accounts receivable		(60)	(27)	(65)
Affiliated receivables and payables		(14)	125	220
Inventories		13	3	20
Deferred fuel and purchased gas costs, net		(269)	(59)	69
Prepayments		(1)	3	8
Accounts payable		(26)	(42)	25
Accrued interest, payroll and taxes		(8)	17	49
Net realized and unrealized changes related to derivative activities		119	13	(153)
Asset retirement obligations		(54)	(88)	(59)
Other operating assets and liabilities		188	(181)	77
Net cash provided by operating activities		2,840	2,961	3,269
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(2,228)	(2,496)	(2,489)
Purchases of nuclear fuel		(173)	(192)	(153)
Acquisition of solar development projects		(141)	(41)	(7)
Proceeds from sales of securities		887	849	733
Purchases of securities		(925)	(884)	(775)
Other		(63)	(41)	(33)
Net cash used in investing activities		(2,643)	(2,805)	(2,724)
Financing Activities
Issuance (repayment) of short-term debt, net		(228)	477	(1,591)
Issuance (repayment) of affiliated current borrowings, net		191	(229)	(114)
Issuance and remarketing of long-term debt		1,300	1,500	1,688
Repayment and repurchase of long-term debt		(964)	(681)	(517)
Common dividend payments		(464)	(1,199)
Other		(18)	(11)	(18)
Net cash provided by (used in) financing activities		(183)	(143)	(552)
Increase (decrease) in cash, restricted cash and equivalents		14	13	(7)
Cash, restricted cash and equivalents at beginning of year		24	11	18
Cash, restricted cash and equivalents at end of year		38	24	11
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		498	458	435
Income taxes		128	362	79
Significant noncash investing and financing activities:
Accrued capital expenditures		204	169	256
Dominion Energy Gas Holdings, LLC
Operating Activities
Net income		301	615	392
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		244	227	204
Deferred income taxes and investment tax credits		33	27	238
Gains on sales of assets and equity method investments		(109)	(70)	(50)
Impairment of assets and related charges		348	15
Other adjustments		(7)	(7)	(6)
Changes in:
Accounts receivable		(14)	(17)	(68)
Affiliated receivables and payables		3	40	88
Inventories		(1)	6	8
Prepayments		(4)	(18)	(6)
Accounts payable		(5)	(17)	15
Accrued interest, payroll and taxes		15	24	42
Pension and other postretirement benefits		(155)	(143)	(141)
Other operating assets and liabilities		(17)	(16)	(68)
Net cash provided by operating activities		632	666	648
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(772)	(778)	(854)
Proceeds from sale of equity method investment in Iroquois				7
Proceeds from assignment of shale development rights		109	70	10
Other		(16)	(19)	(12)
Net cash used in investing activities		(679)	(727)	(849)
Financing Activities
Issuance (repayment) of short-term debt, net		(619)	169	69
Issuance (repayment) of affiliated current borrowings, net		200	(100)	23
Issuance and remarketing of long-term debt		500		680
Repayment and repurchase of long-term debt				(400)
Distribution payments to parent		(25)	(15)	(150)
Other		(5)	(6)	(5)
Net cash provided by (used in) financing activities		51	48	217
Increase (decrease) in cash, restricted cash and equivalents		4	(13)	16
Cash, restricted cash and equivalents at beginning of year		30	43	27
Cash, restricted cash and equivalents at end of year		34	30	43
Supplemental Cash Flow Information
Interest and related charges, excluding capitalized amounts		95	89	81
Income taxes		79	9	(92)
Significant noncash investing and financing activities:
Accrued capital expenditures		$ 38	$ 38	$ 59
[1]	See Note 19 for noncash activities related to the remeasurement of Dominion Energy's noncontrolling interest in Dominion Energy Midstream.
[2]	See Note 9 for noncash activities related to equity method investments.

Nature Of Operations

Nature Of Operations	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature Of Operations	N OTE ATURE OF PERATIONS Dominion Energy, headquartered in Richmond, Virginia, is one of the nation’s largest producers and transporters of energy. Dominion Energy’s operations are conducted through various subsidiaries, including Virginia Power and Dominion Energy 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 Energy. Dominion Energy 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 Dominion Energy’s operations also include the Cove Point LNG Facility, Cove Point Pipeline, Liquefaction Project, an equity investment in Atlantic Coast Pipeline and regulated gas transportation and distribution operations primarily in the eastern and Rocky Mountain regions of the U.S. Dominion Energy’s nonregulated operations include merchant generation, energy marketing and price risk management activities and retail energy marketing operations. At December 31, 2018, Dominion Energy owned the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy Midstream, which owned a preferred equity interest and the general partner interest in Cove Point, DECG, Dominion Energy Questar Pipeline and a 25.93% noncontrolling partnership interest in Iroquois. In January 2019, Dominion Energy acquired all outstanding partnership interests not owned by Dominion Energy and Dominion Energy Midstream became a wholly-owned subsidiary of Dominion Energy. At December 31, 2018, the public’s ownership interest in Dominion Energy Midstream is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Through December 2018, Dominion Energy managed its daily operations through three primary operating segments: Power Delivery, Power Generation and Gas Infrastructure. Dominion Energy also reports a Corporate and Other segment, which includes its corporate, service company and other functions (including unallocated debt). In addition, Corporate and Other includes specific items attributable to Dominion Energy’s operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or in allocating resources. Subsequent to the SCANA Combination, Dominion Energy manages the operations of SCANA through an additional operating segment, Southeast Energy. Virginia Power manages its daily operations through two primary operating segments: Power Delivery and Power 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 in allocating resources. Dominion Energy Gas manages its daily operations through one primary operating segment: Gas Infrastructure. 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 or in allocating resources and the effect of certain items recorded at Dominion Energy Gas as a result of Dominion Energy’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, 2018
Accounting Policies [Abstract]
Significant Accounting Policies	N OTE IGNIFICANT CCOUNTING 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, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned non-Dominion The Companies report certain contracts, instruments and investments at fair value. See Note 6 for further information on fair value measurements. The Companies consider acquisitions or dispositions in which substantially all of the fair value of the gross assets acquired or disposed of is concentrated into a single identifiable asset or group of similar identifiable assets to be an acquisition or a disposition of an asset, rather than a business. See Notes 3 and 10 for further information on such transactions. Dominion Energy maintains pension and other postretirement benefit plans. Virginia Power and Dominion Energy Gas participate in certain of these plans. See Note 21 for further information on these plans. Certain amounts in the Companies’ 2017 and 2016 Consolidated Financial Statements and Notes have been reclassified to conform to the 2018 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows. Amounts disclosed for Dominion Energy are inclusive of Virginia Power and/or Dominion Energy 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 Energy and Virginia Power collect sales, consumption and consumer utility taxes and Dominion Energy Gas collects sales taxes; however, these amounts are excluded from revenue. Dominion Energy’s customer receivables at December 31, 2018 and 2017 included $626 million and $661 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, 2018 and 2017 included $392 million and $400 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. Dominion Energy Gas’ customer receivables at December 31, 2018 and 2017 included $131 million and $121 million, respectively, of accrued unbilled revenue based on estimated amounts of natural gas delivered but not yet billed to its customers. See Note 24 for amounts attributable to related parties. The primary types of sales and service activities reported as operating revenue for Dominion Energy, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated electric sales • Nonregulated electric sales • Regulated gas sales • Nonregulated gas sales • Regulated gas transportation and storage sales • Nonregulated gas transportation and storage sales • Other regulated revenue • Other nonregulated revenue O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated electric sales • Nonregulated electric sales • Regulated gas sales • Nonregulated gas sales • Gas transportation and storage sales • Other revenue The primary types of sales and service activities reported as operating revenue for Virginia Power, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated electric sales • Other regulated revenue • Other nonregulated revenue non-jurisdictional O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Virginia Power, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated electric sales • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated gas sales • Nonregulated gas sales • Regulated gas transportation and storage sales • NGL revenue • Management service revenue • Other regulated revenue • Other nonregulated revenue O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated gas sales • Nonregulated gas sales • Gas transportation and storage sales • NGL revenue • Other revenue Dominion Energy and Virginia Power record refunds to customers as required by state commissions as a reduction to regulated electric sales or regulated gas sales, as applicable. Dominion Energy and Virginia Power’s revenue accounted for under the alternative revenue program guidance primarily consists of the equity return for under-recovery of certain riders. Alternative revenue programs compensate Dominion Energy and Virginia Power for certain projects and initiatives. Revenues arising from these programs are presented separately from revenue arising from contracts with customers in the categories above. Revenues from electric and gas sales are recognized over time, as the customers of the Companies consume gas and electricity as it is delivered. Transportation and storage contracts are primarily stand-ready service contracts that include fixed reservation and variable usage fees. LNG terminalling services are also stand-ready service contracts, primarily consisting of fixed fees, offset by service credits associated with the start-up Dominion Energy and Dominion Energy Gas typically receive or retain NGLs and natural gas from customers when providing natural gas processing, transportation or storage services. The revised guidance for revenue from contracts with customers requires entities to include the fair value of the noncash consideration in the transaction price. Therefore, subsequent to the adoption of the revised guidance for revenue recognition from contracts with customers, Dominion Energy and Dominion Energy Gas record the fair value of NGLs received during natural gas processing as service revenue recognized over time, and continue to recognize revenue from the subsequent sale of the NGLs to customers upon delivery. Dominion Energy and Dominion Energy Gas typically retain natural gas under certain transportation service arrangements that are intended to facilitate performance of the service and allow for natural losses that occur. As the intent of the allowance is to enable fulfillment of the contract rather than to provide compensation for services, the fuel allowance is not included in revenue. Electric Fuel, Purchased Energy and Purchased Gas-Deferred Where permitted by regulatory authorities, the differences between Dominion Energy and Virginia Power’s actual electric fuel and purchased energy expenses and Dominion Energy and Dominion Energy 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, at December 31, 2018, approximately 84% is subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms. Virtually all of Dominion Energy Gas, Cove Point, Questar Gas, Hope and SCE&G and PSNC’s, following the SCANA Combination, 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 Energy and its subsidiaries, including Virginia Power and Dominion Energy Gas’ subsidiaries. In addition, where applicable, combined income tax returns for Dominion Energy and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Although Dominion Energy 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 Energy. Virginia Power and Dominion Energy Gas participate in intercompany tax sharing agreements with Dominion Energy 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 Energy consolidated group members. Otherwise, the net operating loss or credit is carried forward and is recognized as a deferred tax asset until realized. The 2017 Tax Reform Act included a broad range of tax reform provisions affecting the Companies, including changes in corporate tax rates and business deductions. The 2017 Tax Reform Act reduces the corporate income tax rate from 35% to 21% for tax years beginning after December 31, 2017. Deferred tax assets and liabilities are classified as noncurrent in the Consolidated Balance Sheets and measured at the enacted tax rate expected to apply when temporary differences are realized or settled. Thus, at the date of enactment, federal deferred taxes were remeasured based upon the new 21% tax rate. The total effect of tax rate changes on deferred tax balances was recorded as a component of the income tax provision related to continuing operations for the period in which the law is enacted, even if the assets and liabilities relate to other components of the financial statements, such as items of accumulated other comprehensive income. For Dominion Energy subsidiaries that are not rate-regulated utilities, existing deferred income tax assets or liabilities were adjusted for the reduction in the corporate income tax rate and allocated to continuing operations. Dominion Energy’s rate-regulated utility subsidiaries likewise were required to adjust deferred income tax assets and liabilities for the change in income tax rates. However, if it is probable that the effect of the change in income tax rates will be recovered or refunded in future rates, the regulated utility recorded a regulatory asset or liability instead of an increase or decrease to deferred income tax expense. 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 The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not If it is not more-likely-than-not 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. Interest for the Companies was immaterial in 2018 and 2016. Dominion Energy and Virginia Power both recognized interest income of $11 million in 2017. Dominion Energy Gas’ interest was immaterial in 2017. Dominion Energy, Virginia Power and Dominion Energy Gas’ penalties were immaterial in 2018, 2017 and 2016. At December 31, 2018, Virginia Power had an income tax-related In addition, Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2018 included $13 million of state income taxes receivable. State income taxes receivable at Virginia Power were immaterial at December 31, 2018. At December 31, 2017, Virginia Power had an income tax-related In addition, Virginia Power’s Consolidated Balance Sheet at December 31, 2017 included $1 million of noncurrent federal income taxes receivable, less than $1 million of state income taxes receivable and $1 million of noncurrent state income taxes receivable. Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 included $14 million of state income taxes receivable. Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold. Cash, Restricted Cash and Equivalents Cash, restricted cash and equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less. 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: At December 31, 2018 2017 (millions) Dominion Energy $ 35 $ 30 Virginia Power 16 17 Dominion Energy Gas 7 7 R ESTRICTED ASH AND QUIVALENTS The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for customer deposits, future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements and on Eagle Solar’s senior note agreement. The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2018, 2017 and 2016: Cash, Restricted Cash and Equivalents at December 31, December 31, December 31, December 31, (millions) Dominion Energy Cash and cash equivalents $ 268 $ 120 $ 261 $ 607 Restricted cash and equivalents (1) 123 65 61 25 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 391 $ 185 $ 322 $ 632 Virginia Power Cash and cash equivalents $ 29 $ 14 $ 11 $ 18 Restricted cash and equivalents (1) 9 10 — — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 38 $ 24 $ 11 $ 18 Dominion Energy Gas Cash and cash equivalents $ 10 $ 4 $ 23 $ 13 Restricted cash and equivalents (1) 24 26 20 14 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 34 $ 30 $ 43 $ 27 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets. D ISTRIBUTIONS FROM QUITY ETHOD NVESTEES Dominion Energy and Dominion Energy Gas each hold investments that are accounted for under the equity method of accounting. Dominion Energy and Dominion Energy Gas classify distributions from equity method investees as either cash flows from operating activities or cash flows from investing activities in the Consolidated Statements of Cash Flows according to the nature of the distribution. Distributions received are classified on the basis of the nature of the activity of the investee that generated the distribution as either a return on investment (classified as cash flows from operating activities) or a return of an investment (classified as cash flows from investing activities) when such information is available to Dominion Energy and Dominion Energy Gas. Derivative Instruments 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 and foreign currency exchange rate risks of their business operations. Dominion Energy uses derivative instruments such as physical and financial forwards, futures, swaps, options and FTRs to manage the commodity, interest rate and foreign currency exchange rate risks of its business operations. Virginia Power uses derivative instruments such as physical and financial forwards, futures, swaps, options and FTRs to manage commodity and interest rate risks. Dominion Energy Gas uses derivative instruments such as physical and financial forwards, futures and swaps to manage commodity, interest rate and foreign currency exchange 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 Energy had margin assets of $95 million and $92 million associated with cash collateral at December 31, 2018 and 2017, respectively. Dominion Energy’s margin liabilities associated with cash collateral were less than $1 million at December 31, 2018 and 2017. Virginia Power had margin assets of $23 million associated with cash collateral at December 31, 2017. Virginia Power had no margin assets associated with cash collateral at December 31, 2018 and no margin liabilities associated with cash collateral at December 31, 2018 and 2017. Dominion Energy Gas had no margin assets or liabilities associated with cash collateral at December 31, 2018 and 2017. See Note 7 for further information about derivatives. To manage price risk, the Companies hold certain derivative instruments that are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices. All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses, interest and related charges or other income based on the nature of the underlying risk. 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 NSTRUMENTS ESIGNATED AS EDGING NSTRUMENTS In accordance with accounting guidance pertaining to derivatives and hedge accounting, the Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. 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 Dominion Energy entered into interest rate derivative instruments to hedge its forecasted interest payments related to planned debt issuances in 2014. These interest rate derivatives were designated by Dominion Energy as cash flow hedges prior to the formation of Dominion Energy Gas. For the purposes of the Dominion Energy Gas financial statements, the derivative balances, AOCI balance, and any income statement impact related to these interest rate derivative instruments entered into by Dominion Energy have been, and will continue to be, included in the Dominion Energy Gas’ Consolidated Financial Statements as the forecasted interest payments related to the debt issuances now occur at Dominion Energy Gas. Fair Value Hedges 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 In 2018, 2017 and 2016, Dominion Energy capitalized interest costs and AFUDC to property, plant and equipment of $134 million, $236 million and $159 million, respectively. In 2018, 2017 and 2016, Virginia Power capitalized AFUDC to property, plant and equipment of $56 million, $37 million and $21 million, respectively. In 2018, 2017 and 2016, Dominion Energy Gas capitalized AFUDC to property, plant and equipment of $18 million, $25 million and $8 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 2018, 2017 and 2016, Virginia Power recorded $4 million, $22 million and $31 million of AFUDC related to these projects, respectively. For property subject to cost-of-service cost-of-service plant-in-service after-tax) For property that is not subject to cost-of-service 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, 2018 2017 2016 (percent) Dominion Energy Generation 2.71 2.94 2.83 Transmission 2.54 2.55 2.47 Distribution 2.97 3.00 3.02 Storage 2.40 2.48 2.29 Gas gathering and processing 2.62 2.21 2.66 General and other 4.56 4.89 4.12 Virginia Power Generation 2.71 2.94 2.83 Transmission 2.52 2.54 2.36 Distribution 3.31 3.32 3.32 General and other 4.52 4.68 3.49 Dominion Energy Gas Transmission 2.45 2.40 2.43 Distribution 2.41 2.42 2.55 Storage 2.46 2.45 2.19 Gas gathering and processing 3.07 2.42 2.58 General and other 5.59 4.96 4.54 In the second quarter of 2018, Virginia Power recorded an adjustment for the retroactive application of depreciation rates for regulated nuclear plants to comply with Virginia Commission requirements. This adjustment resulted in a decrease of $60 million ($44 million after-tax) after-tax). In the first quarter of 2017, Virginia Power revised the depreciation rates for its assets to reflect the results of a new depreciation study. This change resulted in an increase in annual depreciation expense of $40 million ($25 million after-tax) after-tax) Capitalized costs of development wells and leaseholds are amortized on a field-by-field unit-of-production Dominion Energy’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 15-30 years Nonutility gas gathering and processing 3-50 LNG facility 40 years General and other 5-59 Depreciation and amortization related to Virginia Power and Dominion Energy Gas’ nonutility property, plant and equipment and exploration and production properties was immaterial for the years ended December 31, 2018, 2017 and 2016, except for Dominion Energy Gas’ nonutility gas gathering and processing properties which are depreciated using the straight-line method over estimated useful lives between 10 and 50 years. Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production 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 further discussion on the impairment of long-lived assets. Regulatory Assets and Liabilities The accounting for Dominion Energy and Dominion Energy Gas’ regulated gas and Dominion Energy 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 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, for which a legal obligation exists. 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. Quarterly, the Companies assess their AROs to determine if circumstances indicate that estimates of the amounts or timing of future cash flows associated with retirement activities have changed. AROs are adjusted when significant changes in the amounts or timing of future cash flows are identified. Dominion Energy and Dominion Energy 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. Dominion Energy, following the SCANA Combination, and Virginia Power report 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, Dominion Energy and Virginia Power report accretion of AROs and depreciation on asset retirement costs associated with certain rider and 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 a reduction in long-term debt 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. 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. Investments D EBT AND QUITY ECURITIES WITH EADILY ETERMINABLE AIR ALUES Dominion Energy accounts for and classifies investments in debt securities as trading or available-for-sale available-for-sale • Debt securities classified as trading securities • Debt securities classified as available-for-sale available-for-sale after-tax. In determining realized gains and losses for debt securities, the cost basis of the security is based on the specific identification method. Equity securities with readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the nuclear decommissioning trusts. Dominion Energy and Virginia Power record all equity securities with a readily determinable fair value, or for which they are permitted to estimate fair value using NAV (or its equivalent), at fair value in nuclear decommissioning trust funds and other investments in the Consolidated Balance Sheets. However, Dominion Energy and Virginia Power may elect a measurement alternative for equity securities without a readily determinable fair value. Under the measurement alternative, equity securities are reported at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. Dominion Energy and Virginia Power qualitatively assess equity securities reported using the measurement alternative to determine whether an investment is impaired on an ongoing basis. Net realized and unrealized gains and losses on equity securities 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 equity securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts and rabbi trusts, net realized and unrealized gains and losses are included in other income in the Consolidated Statements of Income. E QUITY ECURITIES WITHOUT EADILY ETERMINABLE AIR ALUES The Companies account for illiquid and privately held securities without readily determinable fair values under either the equity method or cost method. Equity securities without readily determinable fair values include: • Equity method investments • Cost method investments O THER HAN EMPORARY MPAIRMENT The Companies periodically review their investments in debt securities and equity method investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in the 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 for Debt Securities • The recognition provisions of other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale held-to-maturity. • Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion Energy 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 non-performance Inventories Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory is valued using the weighted-average cost method, except for East Ohio gas distribution operations, which are valued using the LIFO method. Under the LI

Acquisitions And Dispositions

Acquisitions And Dispositions	12 Months Ended
	Dec. 31, 2018
Text Block [Abstract]
Acquisitions And Dispositions	N OTE CQUISITIONS ND ISPOSITIONS D OMINION NERGY Acquisition of SCANA In January 2019, Dominion Energy issued 95.6 million shares of Dominion Energy common stock, valued at $6.8 billion, representing 0.6690 of a share of Dominion Energy common stock for each share of SCANA common stock, in connection with the completion of the SCANA Combination. SCANA, through its regulated subsidiaries, is primarily engaged in the generation, transmission and distribution of electricity in the central, southern, and southwestern portions of South Carolina and in the distribution of natural gas in North Carolina and South Carolina. In addition, SCANA markets natural gas to retail customers in the southeast U.S. Following completion of the SCANA Combination, SCANA operates as a wholly-owned subsidiary of Dominion Energy. In addition, SCANA’s outstanding debt totaled $6.9 billion at closing. The SCANA Combination expands Dominion Energy’s portfolio of regulated electric generation, transmission and distribution and regulated natural gas distribution infrastructure and operations. M ERGER PPROVAL AND ONDITIONS Merger Approval The SCANA Combination required approval of SCANA’s shareholders, FERC, the North Carolina Commission, the South Carolina Commission, the Georgia Public Service Commission and the NRC and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. All such approvals were received prior to closing of the SCANA Combination. Various parties filed petitions for rehearing or reconsideration of the SCANA Merger Approval Order. In January 2019, the South Carolina Commission issued a directive (1) granting the request of various parties and finding that SCE&G was imprudent in its actions by not disclosing material information to the South Carolina Office of Regulatory Staff and the South Carolina Commission with regard to costs incurred subsequent to March 2015 and (2) denying the petitions for rehearing or consideration as to other issues raised in the various petitions. The SCANA Merger Approval Order and the order on rehearing are subject to appeal by various parties. Refunds to Customers As a condition to the SCANA Merger Approval Order, SCE&G will provide refunds and restitution of $2.0 billion over 20 years with capital support from Dominion Energy. In September and October 2017, SCE&G received proceeds from Toshiba Corporation totaling $1.1 billion in full satisfaction of its share of a settlement agreement between SCE&G, Santee Cooper and Toshiba Corporation in connection with Westinghouse and WECTEC, both wholly-owned subsidiaries of Toshiba Corporation and responsible for the engineering and construction of the NND Project, filing for bankruptcy. The purchase price allocation below includes a previously established regulatory liability at SCE&G totaling $1.1 billion associated with the monetization of the bankruptcy settlement with Toshiba Corporation. In accordance with the terms of the SCANA Merger Approval Order, this regulatory liability, net of amounts that may be required to satisfy any liens against NND Project property totaling $1.0 billion, will be refunded to SCE&G electric service customers over a 20-year Additionally, SCE&G will reflect in the first quarter of 2019 a reduction in operating revenue and a corresponding regulatory liability of $1.0 billion of which approximately $140 million will be considered current, representing a refund of amounts previously collected from retail electric customers of SCE&G for the NND Project to be credited over an estimated 11-year NND Project As a condition to the SCANA Merger Approval Order, SCE&G will exclude from rate recovery $2.4 billion of costs related to the NND Project and $180 million of costs associated with the purchase of the Columbia Energy Center power station. Regulatory assets included in SCANA’s historical balance sheet at December 31, 2018 reflected these disallowances. The remaining regulatory asset associated with the NND Project of $2.8 billion will be collected over a 20-year period, including a return on investment. In January 2019, SCE&G filed the NND Project rider in accordance with the terms of the SCANA Merger Approval Order for rates effective in February 2019 for SCE&G’s retail electric customers. The South Carolina Commission approved this filing in January 2019. Other Terms and Conditions • SCE&G will not file an application for a general rate case with the South Carolina Commission with a requested effective date earlier than January 2021; • PSNC will not file an application for a general rate case with the North Carolina Commission with a requested effective date earlier than April 2021; • Dominion Energy has committed to increasing SCANA’s historical level of corporate contributions to charities by $1 million per year over the next five years; • Dominion Energy will maintain SCE&G and PSNC’s headquarters in Cayce, South Carolina and Gastonia, North Carolina, respectively; and • Dominion Energy will seek to minimize reductions in local employment by allowing some DES employees supporting shared and common services functions and activities to be located in Cayce, South Carolina where it makes economic and practical sense to do so. P URCHASE RICE LLOCATION SCANA’s assets acquired and liabilities assumed will be measured at estimated fair value at closing and will be included in the Southeast Energy operating segment, which was established following the closing of the SCANA Combination. The majority of the operations acquired are subject to the rate setting authority of FERC and the North and South Carolina Commissions and are therefore accounted for pursuant to ASC 980, Regulated Operations The fair value of SCANA’s assets acquired and liabilities assumed that are not subject to the rate-setting provisions discussed above and the fair values of SCANA’s investments accounted for under the equity method will be determined using the income approach and the market approach. The valuation of SCANA’s long-term debt is considered a Level 2 fair value measurement. All other valuations will be considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in the future market prices. The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed will be reflected as goodwill in the first quarter of 2019. The goodwill reflects the value associated with enhancing Dominion Energy’s portfolio of regulated operations in the growing southeast region of the U.S. The goodwill to be recognized will not be deductible for income tax purposes, and as such, no deferred taxes will be recorded related to goodwill. The table below shows the preliminary allocation of the purchase price to the assets acquired and liabilities assumed at closing to be reflected in Dominion Energy’s Consolidated Balance Sheet in the first quarter of 2019. The allocation is subject to change during the measurement period as additional information is obtained about the facts and circumstances that existed at closing. The allocation of the purchase price excludes certain contracts and intangible assets related to nonregulated operations, including SEMI, equity method investments and certain income tax-related Amount (millions) Total current assets $ 1,756 Investments 213 Property, plant and equipment, net 10,982 Goodwill 2,438 Regulatory assets 4,219 Other deferred charges and other assets, including intangible assets 314 Total Assets 19,922 Total current liabilities 1,506 Long-term debt 6,707 Deferred income taxes 1,097 Regulatory liabilities 2,664 Other deferred credits and other liabilities 1,109 Total Liabilities 13,083 Total purchase price $ 6,839 I NFORMATION ON SSETS AND IABILITIES CQUIRED Cash, Restricted Cash and Equivalents The total current assets line above includes $389 million of cash, restricted cash and equivalents, of which $115 million is considered restricted, acquired by Dominion Energy in connection with the SCANA Combination. Investments Investments acquired in connection with the SCANA Combination include $20 million pertaining to certain investments accounted for under the equity method, at carrying value. Dominion Energy is still assessing the fair value of these investments. Income Taxes Deferred income taxes include a deferred tax asset recorded on a federal net operating loss carryforward of $1.8 billion and a state net operating loss carryforward of $2.4 billion. Based on the available evidence, Dominion Energy believes it is more likely than not that the benefit of the federal net operating loss will be utilized during the carryforward period, and therefore no valuation allowance has been established. Dominion Energy is still assessing whether a valuation allowance is required on the state net operating loss carryforward. Deferred income taxes also include unrecognized tax benefits of $106 million, which could increase as Dominion Energy continues and completes its evaluation of positions taken on SCANA’s federal and state income tax returns. Property, Plant and Equipment At the date of the SCANA Combination, major classes of property, plant and equipment and their respective balances for SCANA are as follows: 2018 (millions) Utility: Generation $ 5,720 Transmission 2,416 Distribution 6,044 Storage 99 Nuclear fuel 611 General and other 631 Plant under construction 527 Total utility 16,048 Nonutility, including plant under construction 283 Total property, plant and equipment $ 16,331 In connection with the SCANA Combination, Dominion Energy intends to forego recovery of approximately $105 million of certain assets for which it expects to recognize a $79 million after-tax charge in the first quarter of 2019. Regulated property will be depreciated on a straight-line basis based on projected service lives. Actual average composite depreciation rates for SCANA’s utility property, plant and equipment were as follows: 2018 (millions) Generation 2.61 % Transmission 2.47 Distribution 2.48 Storage 2.48 General and other 5.64 Nonregulated property, plant and equipment, excluding land, will be depreciated on a straight-line basis over the remaining useful lives of such property, primarily ranging from 5 to 78 years. SCE&G jointly owns and is the operator of Summer. At December 31, 2018, and subsequent to the SCANA Combination, SCE&G had a 66.7% ownership interest in Summer, of which its proportionate share of plant in service, accumulated depreciation and plant under construction was $1.5 billion, $644 million and $128 million, respectively. The co-owners Regulatory Assets In addition to the items discussed above related to the NND Project, Dominion Energy intends to forego recovery of approximately $190 million of regulatory assets related to certain deferred income taxes for which it expects to recognize a $145 million after-tax charge in the first quarter of 2019. Intangible Assets Other current assets presented in the table above include intangible assets subject to regulatory recovery with a gross carrying value of $281 million and related accumulated amortization of $181 million. Such intangible assets have an estimated weighted-average amortization period of approximately five years. Annual amortization expense for these intangible assets is estimated to be as follows: 2019 2020 2021 2022 2023 (millions) SCANA $ 95 $ 90 $ 80 $ 74 $ 71 Asset Retirement Obligations The purchase price allocation above includes $577 million of AROs, of which $23 million is considered to be a current liability. These AROs are associated with SCANA’s legal obligation to decommission Summer, as well as conditional obligations related to generation, transmission and distribution properties, including gas pipelines. Short-Term and Long-Term Debt At closing of the SCANA Combination, commercial paper and letters of credit outstanding, as well as capacity available under SCANA’s existing credit facilities were as follows: SCANA Corporation SCE&G PSNC Total (millions, except percentages) Total facility limit $ 400 $ 1,200 (1) $ 200 $ 1,800 Letters of credit advances 40 (2) — — 40 Weighted-average interest rate 3.87 % n/a n/a 3.87 % Outstanding commercial paper 2 73 98 173 Weighted-average interest rate 3.65 % 3.82 % 3.49 % 3.63 % Outstanding letters of credit 37 — — 37 Facility capacity available $ 321 $ 1,127 $ 102 $ 1,550 (1) Includes South Carolina Fuel Company, Inc.’s $500 million credit facility. (2) In January 2019, SCANA repaid $40 million in letter of credit advances. In connection with the SCANA Combination, Dominion Energy intends to terminate SCANA, SCE&G and PSNC’s existing credit facilities, scheduled to expire in December 2020, and add SCE&G as a co-borrower co-borrowers, At closing of the SCANA Combination, SCANA had the following long-term debt outstanding which is part of the total consideration provided for the transaction. Weighted- average Coupon (1) Amount (millions, except percentages) Unsecured medium term notes, due 2020 to 2022 5.42 % $ 800 Unsecured senior notes, due 2019 to 2034 3.44 70 First mortgage bonds, due 2021 to 2065 5.52 4,990 GENCO notes, due 2019 to 2024 5.49 40 Industrial and pollution control bonds, due 2028 to 2038 (2) 3.52 122 PSNC senior debentures and notes, due 2020 to 2047 5.07 700 Other, due 2019 to 2027 3.46 73 Total principal $ 6,795 Current maturities of long-term debt (59 ) Unamortized discount, premium and debt issuance costs, net (29 ) SCANA total long-term debt $ 6,707 (1) Represents weighted-average coupon rates for debt outstanding at closing of the SCANA Combination. (2) Includes variable rate debt of $68 million, with a weighted-average interest rate of 1.72%, which is hedged by fixed swaps. 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 closing of the SCANA Combination, were as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions, except Unsecured senior notes $ 4 $ 4 $ 4 $ 4 $ 4 $ 50 $ 70 Unsecured medium term notes — 250 300 250 — — 800 First mortgage bonds — — 330 — — 4,660 4,990 PSNC senior debentures and notes — 100 150 — — 450 700 GENCO notes 7 7 7 7 7 5 40 Industrial and pollution control bonds — — — — — 122 122 Other 48 7 6 5 3 4 73 Total $ 59 $ 368 $ 797 $ 266 $ 14 $ 5,291 $ 6,795 Weighted-average coupon 3.91 % 6.26 % 4.20 % 5.22 % 3.29 % 5.51 % 5.36 % In February 2019, SCANA launched a tender offer for certain of its medium term notes having an aggregate purchase price of up to $300 million that expires in March 2019. Also in February 2019, SCE&G launched a tender offer for any and all of certain of its first mortgage bonds pursuant to which it purchased first mortgage bonds having an aggregate purchase price of $1.0 billion. SCE&G simultaneously launched a tender offer that expires in March 2019 for certain other of its first mortgage bonds having an aggregate purchase price equal to $1.2 billion less the aggregate purchase price paid in the any and all tender offer. Preferred Stock At the closing of the SCANA Combination, authorized shares of SCE&G preferred stock were 20 million, of which 1,000 shares, no par value, were held by SCANA. R EGULATORY ATTERS AND ROCEEDINGS Base Load Review Act In 2016, the South Carolina Commission approved revised rates under the Base Load Review Act allowing the incorporation of financing costs associated with SCE&G’s incremental construction work in progress incurred for the NND Project and setting an allowed ROE of 10.5%. In July 2018, the South Carolina Commission issued orders implementing a June 2018 legislatively-mandated temporary reduction in revenues that could be collected by SCE&G from its electric utility customers under the Base Load Review Act and altering certain provisions previously applicable under the Base Load Review Act, including redefining the standard of care required by the associated regulations and supplying definitions of key terms that would affect the evidence required to establish SCE&G’s ability to recover its costs associated with the NND Project. These orders reduced the portion of SCE&G’s retail electric rates associated with the NND Project from approximately 18% of the average residential electric customer’s bill, which equates to a reduction in revenues of approximately $31 million per month, retroactive to April 2018. These lower rates remained in effect until February 2019, when the new rates pursuant to the SCANA Merger Approval Order became effective. In June 2018, SCE&G filed a lawsuit in the U.S. District Court for the District of South Carolina challenging the constitutionality of the rate reductions under the Base Load Review Act. In the lawsuit, which was subsequently amended, SCE&G sought a declaration that the new laws are unconstitutional. In January 2019, SCE&G voluntarily dismissed this lawsuit. 2017 Tax Reform Act In connection with the SCANA Merger Approval Order, the South Carolina Commission approved SCE&G’s provision of approximately $100 million in bill credits related to the 2017 Tax Reform Act’s impact on retail electric customer rates for the period beginning January 2018 through January 2019. These credits have been included in bills rendered on and after the first billing cycle of February 2019. In addition, the South Carolina Commission approved a tax rider whereby the effects of the reduction in the corporate income tax rate resulting from the 2017 Tax Reform Act will benefit retail electric customers. This tax rider is expected to reduce base rates to retail electric customers by approximately $67 million in each of 2019 and 2020, effective with the first billing cycle of February 2019. In October 2018, the South Carolina Commission issued an order approving adjustment to SCE&G’s natural gas rate schedules, under the terms of the Natural Gas Rate Stabilization Act, to reflect the reduction in the federal corporate tax rate arising from the 2017 Tax Reform Act. The approved natural gas rate schedules also included a tax reform rate rider to refund certain income tax amounts previously collected from customers. These lower rates, representing a $20 million decreased revenue requirement, became effective for bills rendered on and after the first billing cycle in November 2018. In December 2018, the North Carolina Commission issued an order approving PSNC’s proposed adjustments to customer rates, representing a $13 million decreased revenue requirement, to reflect the reduction in the federal corporate tax rate arising from the 2017 Tax Reform Act. These lower rates became effective for service rendered on and after January 1, 2019. Amounts collected in customer rates during 2018 and amounts arising from excess deferred income taxes have been recorded in regulatory liabilities and must be considered in PSNC’s next general rate case proceeding or in three years, whichever is sooner. The reduction in the federal corporate tax rate and its impact on PSNC’s various rate riders will be addressed in future proceedings related to those riders. DSM Programs SCE&G has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January 2019, SCE&G filed an application with the South Carolina Commission seeking approval to recover $30 million of costs and net lost revenues associated with these programs, along with an incentive to invest in such programs. This matter is pending. L EGAL ROCEEDINGS The following describes certain legal proceedings to which SCANA or SCE&G were a party to at closing of the SCANA Combination. Dominion Energy intends to vigorously contest the lawsuits, claims and assessments which have been filed or initiated against SCANA and SCE&G. No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material. Due to the uncertainty surrounding these matters, Dominion Energy is unable to make an estimate of the potential financial statement impacts; however, they could have a material impact on its results of operations, financial condition and/or cash flows. Ratepayer Class Actions In May 2018, a consolidated complaint against SCE&G, SCANA, and the State of South Carolina was filed in the State Court of Common Pleas in Hampton County, South Carolina (the SCE&G Ratepayer Case). In September 2018, the court certified this case as a class action. The plaintiffs allege, among other things, that SCE&G was negligent and unjustly enriched, breached alleged fiduciary and contractual duties and committed fraud and misrepresentation in failing to properly manage the NND Project, and that SCE&G committed unfair trade practices and violated state anti-trust laws. The plaintiffs sought a declaratory judgment that SCE&G may not charge its customers for any past or continuing costs of the NND Project, sought to have SCANA and SCE&G’s assets frozen and all monies recovered from Toshiba Corporation and other sources be placed in a constructive trust for the benefit of ratepayers and sought specific performance of the alleged implied contract to construct the NND Project. In December 2018, the State Court of Common Pleas in Hampton County entered an order granting preliminary approval of a class action settlement and a stay of pre-trial In September 2017, a purported class action was filed against Santee Cooper, SCE&G, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. in the State Court of Common Pleas in Hampton County, South Carolina (the Santee Cooper Ratepayer Case). The allegations are substantially similar to those in the SCE&G Ratepayer Case. The plaintiffs seek a declaratory judgment that the defendants may not charge the purported class for reimbursement for past or future costs of the NND Project. In March 2018, the plaintiffs filed an amended complaint including as additional named defendants, including certain then current and former directors of Santee Cooper and SCANA. In June 2018, Santee Cooper filed a Notice of Petition for Original Jurisdiction with the Supreme Court of South Carolina. In December 2018, Santee Cooper filed its answer to the plaintiffs’ fourth amended complaint and filed cross claims against SCE&G. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. RICO Class Action In January 2018, a purported class action was filed, and subsequently amended, against SCANA, SCE&G and certain former executive officers in the U.S. District Court for the District of South Carolina. The plaintiff alleges, among other things, that SCANA, SCE&G and the individual defendants participated in an unlawful racketeering enterprise in violation of RICO and conspired to violate RICO by fraudulently inflating utility bills to generate unlawful proceeds. The SCE&G Ratepayer Class Action settlement described previously contemplates dismissal of claims by SCE&G ratepayers in this case against SCE&G, SCANA and their officers. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. State Court Shareholder Actions In September 2017, a purported shareholder derivative action was filed against certain former executive officers and directors of SCANA in the State Court of Common Pleas in Richland County, South Carolina. In September 2018, this action was consolidated with another action in the Business Court Pilot Program in Richland County. The plaintiffs allege, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the NND Project, and that the defendants were unjustly enriched by bonuses they were paid in connection with the project. The defendants have filed a motion to dismiss the consolidated action in favor of the pending federal derivative action. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. In January 2018, a purported class action was filed against SCANA, Dominion Energy and certain former executive officers and directors in the State Court of Common Pleas in Lexington County, South Carolina (the City of Warren Lawsuit). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the merger. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina, and filed a Motion to Dismiss in March 2018. In June 2018, the case was remanded back to the State Court of Common Pleas in Lexington County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal has been consolidated with a similar appeal and remains pending. In October 2018, the U.S. District Court for the District of South Carolina granted Dominion Energy’s motion to stay pending appeal. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. In February 2018, a purported class action was filed against certain former directors of SCANA and SCE&G and Dominion Energy in the State Court of Common Pleas in Richland County, South Carolina. The allegations made and the relief sought by the plaintiffs are substantially similar to that described for the City of Warren Lawsuit. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina, and filed a Motion to Dismiss in March 2018. In August 2018, the case was remanded back to the State Court of Common Pleas in Richland County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal has been consolidated with the City of Warren Lawsuit. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. Federal Court Shareholder Action In November 2017, a purported shareholder derivative action was filed against SCANA and certain former executive officers and directors in the U.S. District Court of the District of South Carolina. Another purported shareholder derivative action was filed against nearly all of these defendants. In January 2018, the U.S. District Court for the District of South Carolina consolidated these suits, and the plaintiffs filed a consolidated amended complaint. The plaintiffs allege, among other things, that the defendants violated their fiduciary duties to shareholders by disseminating false and misleading information about the NND Project, failing to maintain proper internal controls, failing to properly oversee and manage SCANA and that the individual defendants were unjustly enriched in their compensation. In June 2018, the court denied the defendants’ motions to dismiss and in October 2018, the court denied SCANA’s motion to stay all proceedings pending investigation by a Special Litigation Committee, with leave to refile after the SCANA Merger Approval Order was issued. The plaintiffs have agreed to a stay of this action on the condition that defendants file a motion for judgment on the pleadings, which was filed in January 2019. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows. Federal Court 10b-5 In September 2017, a purported class action was filed against SCANA and certain former executive officers and directors in the U.S. District Court for the District of South Carolina. Subsequent additional purported class actions were separately filed against all or nearly all of these defendants. In January 2018, the U.S. District Court for the District of South Carolina consolidated these suits, and the plaintiffs filed a consolidated amended complaint in March 2018. The plaintiffs allege, among other things, that the defendants violated §10(b) of the Securities Exchange Act of 1934, as amended, and Rule 10b-5 Employment Class Action and Indemnification In July 2018, a case filed in the U.S. District Court for the District of South Carolina was certified as a class action on behalf of persons who were formerly employed at the NND Project. The plaintiffs allege, among other things, that SCANA, Fluor Corporation and Fluor Enterprises, Inc. violated the Worker Adjustment and Retraining Notification Act in connection with the decision to stop construction at the NND Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment, which is estimated to be as much as $75 million. SCE&G as co-owner of the NND project would have a 55% proportional share in the ultimate outcome. The ultimate loss could rise due to the Fluor defendants seeking indemnification from SCE&G. In September 2018, a case was filed in the State Court of Common Pleas in Fairfield County, South Carolina by Fluor Enterprises, Inc. and Fluor Daniel Maintenance Services, Inc. against SCE&G and Santee Cooper. The plaintiffs make claims for indemnification, breach of contract and promissory estoppel arising from, among other things, the defendants’ alleged failure and refusal to defend and indemnify the Fluor defendants in the aforementioned case. These cases are pending. FILOT Litigation and Related Matters In November 2017, Fairfield County filed a complaint and a motion for temporary injunction against SCE&G in the State Court of Common Pleas in Fairfield County, South Carolina, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of implied duty of good faith and fair dealing and unfair trade practices related to SCE&G’s termination of the FILOT agreement between SCE&G and Fairfield County related to the NND Project. The plaintiff sought a temporary and permanent injunction to prevent SCE&G from terminating the FILOT agreement. The plaintiff withdrew the motion for temporary injunction in December 2017. Dominion Energy is currently unable to make an estimate of the potential impacts to its consolidated financial statements related to this matter. This case is pending. Governmental Proceedings and Investigations In June 2018, SCE&G received a notice of proposed assessment of approximately $410 million, excluding interest, from the SCDOR following its audit of SCE&G’s sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The proposed assessment, which includes 100% of the NND Project, is based on the SCDOR’s position that SCE&G’s sales and use tax exemption for the NND Project does not apply because the facility will not become operational. SCE&G has protested the proposed assessment, which remains pending, and recorded an $11 million liability in its Consolidated Balance Sheet as of December 31, 2018 for its share of any taxes ultimately due. In September and October 2017, SCANA was served with subpoenas issued by the U.S. Attorney’s Office for the District of South Carolina and the Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and SCE&G. These matters are pending. SCANA and SCE&G are cooperating fully with the investigations; however, Dominion Energy cannot currently predict whether or to what extent SCANA or SCE&G may incur a material liability. Other In December 2018, arbitration proceedings commenced between SCE&G and Cameco Corporation related to a supply agreement signed in May 2008. This agreement provides the terms and conditions under which SCE&G agreed to purchase uranium h

Operating Revenue

Operating Revenue	12 Months Ended
	Dec. 31, 2018
Text Block [Abstract]
Operating Revenue	N OTE PERATING EVENUE The Companies’ operating revenue, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, consists of the following: Year Ended December 31, 2018 (millions) Dominion Energy Regulated electric sales: Residential $ 3,413 Commercial 2,503 Industrial 490 Government and other retail 854 Wholesale 137 Nonregulated electric sales 1,294 Regulated gas sales: Residential 818 Commercial 221 Other 36 Nonregulated gas sales 214 Regulated gas transportation and storage: FERC-regulated 1,091 State-regulated 640 Nonregulated gas transportation and storage 442 Other regulated revenues 179 Other nonregulated revenues (1)(2) 563 Total operating revenue from contracts with customers 12,895 Other revenues (2) (3) 471 Total operating revenue $ 13,366 Virginia Power Regulated electric sales: Residential $ 3,413 Commercial 2,503 Industrial 490 Government and other retail 854 Wholesale 137 Other regulated revenues 132 Other nonregulated revenues (1)(2) 55 Total operating revenue from contracts with customers 7,584 Other revenues (1 ) (3) 35 Total operating revenue $ 7,619 Dominion Energy Gas Regulated gas sales: Residential $ 81 Other 27 Nonregulated gas sales (1) 13 Regulated gas transportation and storage: FERC-regulated (1) 763 State-regulated (1) 605 NGL revenue (1)(2) 223 Management service revenue (1) 205 Other regulated revenues (1) 22 Other nonregulated revenues (1) 10 Total operating revenue from contracts with customers 1,949 Other revenues (9 ) Total operating revenue $ 1,940 (1) See Notes 9 and 24 for amounts attributable to related parties and affiliates. (2) Amounts above include $241 million and $206 million for the year ended December 31, 2018 primarily consisting of NGL sales at Dominion Energy and Dominion Energy Gas, respectively, which are considered to be goods transferred at a point in time. In addition, the amounts include $17 million and $11 million of sales of renewable energy credits at both Dominion Energy and Virginia Power for the year ended December 31, 2018, respectively, which are considered to be goods transferred at a point in time. (3) Amounts above include $15 million of alternative revenue at Dominion Energy and Virginia Power for the year ended December 31, 2018. The table below discloses the aggregate amount of the transaction price allocated to fixed-price performance obligations that are unsatisfied (or partially unsatisfied) at the end of the reporting period and when the Companies expect to recognize this revenue. These revenues relate to contracts containing fixed prices where the Companies will earn the associated revenue over time as they stand ready to perform services provided. This disclosure does not include revenue related to performance obligations that are part of a contract with original durations of one year or less. In addition, this disclosure does not include expected consideration related to performance obligations for which the Companies elect to recognize revenue in the amount they have a right to invoice. Revenue expected to be recognized on multi-year contracts in place at December 31, 2018 2019 2020 2021 2022 2023 Thereafter Total (millions) Dominion Energy $ 1,643 $ 1,563 $ 1,448 $ 1,319 $ 1,154 $ 13,693 $ 20,820 Virginia Power 21 3 1 — — — 25 Dominion Energy Gas 600 560 475 384 268 1,612 3,899 Contract assets represent an entity’s right to consideration in exchange for goods and services that the entity has transferred to a customer. At December 31, 2018 and December 31, 2017, Dominion Energy’s contract asset balances were $42 million and $46 million, respectively. Dominion Energy Gas’ contract asset balances were $58 million and $66 million at December 31, 2018 and December 31, 2017, respectively. Dominion Energy and Dominion Energy Gas’ contract assets are recorded in other deferred charges and other assets in the Consolidated Balance Sheets. Contract liabilities represent an entity’s obligation to transfer goods or services to a customer for which the entity has received consideration, or the amount that is due, from the customer. At December 31, 2018 and December 31, 2017, Dominion Energy’s contract liability balances were $106 million and $132 million, respectively. At December 31, 2018 and December 31, 2017, Virginia Power’s contract liability balances were $22 million and $50 million, respectively. At December 31, 2018 and December 31, 2017, Dominion Energy Gas’ contract liability balances were $40 million and $41 million, respectively. During the year ended December 31, 2018, Dominion Energy, Virginia Power and Dominion Energy Gas recognized revenue of $94 million, $25 million and $41 million, respectively, from the beginning contract liability balances as the Companies fulfilled their obligations to provide service to their customers. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the Consolidated Balance Sheets. The Companies’ operating revenue, prior to the adoption of revised guidance for revenue recognition from contracts with customers, consisted of the following: Year Ended December 31, 2017 2016 (millions) Dominion Energy Electric sales: Regulated $ 7,383 $ 7,348 Nonregulated 1,429 1,519 Gas sales: Regulated 1,067 500 Nonregulated 457 354 Gas transportation and storage 1,786 1,636 Other 464 380 Total operating revenue $ 12,586 $ 11,737 Virginia Power Regulated electric sales $ 7,383 $ 7,348 Other 173 240 Total operating revenue $ 7,556 $ 7,588 Dominion Energy Gas Gas sales: Regulated $ 87 $ 119 Nonregulated 20 13 Gas transportation and storage 1,435 1,307 NGL revenue 91 62 Other 181 137 Total operating revenue $ 1,814 $ 1,638

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	N OTE NCOME AXES Judgment and the use of estimates are required in developing the provision for income taxes and reporting of tax-related tax-related The 2017 Tax Reform Act included a broad range of tax reform provisions affecting the Companies as discussed in Note 2. The 2017 Tax Reform Act reduced the corporate income tax rate from 35% to 21% for tax years beginning after December 31, 2017. At the date of enactment, deferred tax assets and liabilities were remeasured based upon the new 21% enacted tax rate expected to apply when temporary differences are realized or settled. The specific provisions related to regulated public utilities in the 2017 Tax Reform Act generally allow for the continued deductibility of interest expense, changed the tax depreciation of certain property acquired after September 27, 2017, and continued certain rate normalization requirements for accelerated depreciation benefits. As indicated in Note 2, certain of the Companies’ operations, including accounting for income taxes, are subject to regulatory accounting treatment. For regulated operations, many of the changes in deferred taxes represent amounts probable of collection from or refund to customers, and were recorded as either an increase to a regulatory asset or liability. The 2017 Tax Reform Act included provisions that stipulate how these excess deferred taxes may be passed back to customers for certain accelerated tax depreciation benefits. Potential refunds of other deferred taxes may be determined by our regulators. See Note 13 for more information. The Companies have accounted for the effects of the 2017 Tax Reform Act, although changes could occur as additional guidance is issued and finalized. In addition, certain states in which the Companies operate may or may not conform to some or all of the provisions of the 2017 Tax Reform Act. Ultimate resolution or clarification of these matters may result in favorable or unfavorable impacts to net income, cash flows, and tax-related Continuing Operations Details of income tax expense for continuing operations including noncontrolling interests were as follows: Dominion Energy Virginia Power Dominion Energy Gas Year Ended December 31, 2018 2017 2016 2018 2017 2016 2018 2017 2016 (millions) Current: Federal $ (45 ) $ (1 ) $ (155 ) $ 36 $ 432 $ 168 $ 23 $ 16 $ (27 ) State 108 (26 ) 85 40 73 90 30 8 4 Total current expense (benefit) 63 (27 ) (70 ) 76 505 258 53 24 (23 ) Deferred: Federal 2017 Tax Reform Act impact 46 (851 ) — 21 (93 ) — (11 ) (197 ) — Taxes before operating loss carryforwards and investment tax credits 436 739 1,050 199 319 435 48 199 239 Tax utilization expense (benefit) of operating loss carryforwards 92 174 (161 ) — 4 (2 ) — 5 (2 ) Investment tax credits (56 ) (200 ) (248 ) (51 ) (23 ) (25 ) — — — State (1 ) 132 50 55 59 27 (4 ) 20 1 Total deferred expense (benefit) 517 (6 ) 691 224 266 435 33 27 238 Investment tax credit-gross deferral 2 5 35 2 5 35 — — — Investment tax credit-amortization (2 ) (2 ) (1 ) (2 ) (2 ) (1 ) — — — Total income tax expense (benefit) $ 580 $ (30 ) $ 655 $ 300 $ 774 $ 727 $ 86 $ 51 $ 215 The 2017 Tax Reform Act reduced the statutory federal income tax rate to 21% beginning in January 2018. Accordingly, current income taxes, and deferred income taxes that originate in 2018, are recorded at the new 21% rate. Dominion Energy had less than $1 million of state deferred income tax expense as a result of the reversal of deferred taxes upon the sale of its interest in Blue Racer and Fairless and Manchester. Dominion Energy’s current federal income taxes primarily include the recognition of a $47 million benefit related to a carryback claim for specified liability losses involving prior tax years. The accounting for the reduction in the corporate income tax rate decreased deferred income tax expense by $851 million at Dominion Energy, $93 million at Virginia Power, and $197 million for Dominion Energy Gas for the year ending December 31, 2017. The decrease in deferred income taxes at Dominion Energy primarily relates to the remeasurement of deferred taxes on merchant operations and includes the effects at Virginia Power and Dominion Energy Gas. Virginia Power and Dominion Energy Gas have certain regulatory assets and liabilities that have not yet been charged or returned to customers through rates, or on which they do not earn a return, including unrecognized pension and other postretirement benefits. The remeasurement of the deferred taxes on these regulatory balances was charged to continuing operations in 2017. For ratemaking purposes, Dominion Energy Gas’ subsidiary DETI follows the cash method on pension contributions. Deferred taxes recorded on pension balances as required by GAAP are not included as a component of rates and therefore the remeasurement of these deferred taxes were charged to continuing operations in 2017. In 2016, Dominion Energy realized a taxable gain resulting from the contribution of Dominion Energy Questar Pipeline to Dominion Energy Midstream. The contribution and related transactions resulted in increases in the tax basis of Dominion Energy Questar Pipeline’s assets and the number of Dominion Energy Midstream’s common and convertible preferred units held by noncontrolling interests. The direct tax effects of the transactions included a provision for current income taxes ($212 million) and an offsetting benefit for deferred income taxes ($96 million) and were charged to common shareholders’ equity. The federal tax liability was reduced by $129 million of tax credits generated in 2016 that otherwise would have resulted in additional credit carryforwards and a $17 million benefit provided by the domestic production activities deduction. These benefits, as indirect effects of the contribution transaction, were reflected in Dominion Energy’s 2016 current federal income tax expense. 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 Energy Virginia Power Dominion Energy Gas Year Ended December 31, 2018 2017 2016 2018 2017 2016 2018 2017 2016 U.S. statutory rate 21.0 % 35.0 % 35.0 % 21.0 % 35.0 % 35.0 % 21.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.0 2.0 2.4 4.7 3.7 3.8 3.2 2.4 0.5 Investment tax credits (1.9 ) (6.3 ) (11.7 ) (3.5 ) (0.8 ) — — — — Production tax credits (0.7 ) (0.7 ) (0.8 ) (0.7 ) (0.4 ) (0.5 ) — — — Valuation allowances 0.3 0.2 1.2 — — 0.1 1.8 0.3 — Reversal of excess deferred income taxes (2.0 ) — — (3.2 ) — — (1.7 ) — — Federal legislative change 1.5 (27.5 ) — 1.3 (4.0 ) — (2.8 ) (29.5 ) — State legislative change (0.6 ) — (0.6 ) — — — 0.2 — — AFUDC—equity (0.8 ) (1.4 ) (0.6 ) (0.5 ) (0.6 ) (0.6 ) (0.6 ) (0.9 ) (0.2 ) Employee stock ownership plan deduction (0.4 ) (0.6 ) (0.6 ) — — — — — — Other, net (0.9 ) (1.7 ) (1.4 ) (0.1 ) 0.6 (0.4 ) 1.2 0.4 0.1 Effective tax rate 18.5 % (1.0 )% 22.9 % 19.0 % 33.5 % 37.4 % 22.3 % 7.7 % 35.4 % For the Companies’ rate-regulated entities, deferred taxes will reverse at the weighted average rate used to originate the deferred tax liability, which in some cases will be 35%. The Companies have recorded an estimate of the portion of excess deferred income tax amortization in 2018, and changes in estimates of amounts probable of collection from or return to customers. The reversal of these excess deferred income taxes will impact the effective tax rate, and may ultimately impact rates charged to customers. As described in Note 13 to the Consolidated Financial Statements, the Companies decreased revenue and increased regulatory liabilities to offset these deferred tax impacts in accordance with applicable regulatory commission orders or formula rate mechanisms. In 2018, the Companies applied the provisions of recently proposed regulations addressing the availability of federal bonus depreciation for the period beginning after September 27, 2017 through December 31, 2017. The application of these changes increased Dominion Energy’s 2017 net operating loss carryforward, the benefit of which will be recognized at the 21% rate. As a result, Dominion Energy’s effective tax rate reflects a $23 million increase to deferred income tax expense associated with the remeasurement of this deferred tax asset. The application of these proposed regulations at Dominion Energy Gas had no impact on income tax expense as the changes in, and remeasurement of, deferred tax liabilities increased regulatory liabilities by $35 million. The effects of these changes at Virginia Power were immaterial. These amounts and adjustments represent the Companies’ best estimate based on available information, and could be subject to change based on additional guidance in yet to be finalized regulations. In addition, changes in estimates of amounts probable of return to or collection from customers increased deferred income tax expense at Virginia Power by $23 million and increased regulatory liabilities by $31 million. At Dominion Energy Gas similar changes in estimates decreased income tax expense by $11 million and regulatory liabilities by $16 million. These changes also impacted Dominion Energy. In addition, Dominion Energy and Dominion Energy Gas’ effective tax rates reflect the impacts of a state legislative change enacted in the second quarter of 2018 that was retroactive to January 1, 2018. In 2017, the Companies’ effective tax rates reflect the net benefit of remeasurement of deferred taxes resulting from the lower corporate income tax rate promulgated by the 2017 Tax Reform Act, and the completion of audits by state tax authorities that resulted in the recognition of previously unrecognized tax benefits. At December 31, 2016, Virginia Power’s unrecognized tax benefits included state refund claims for open tax years through 2011. Management believed settlement of the claims, including interest thereon, within the next twelve months was remote. In June 2017, Virginia Power received and accepted a cash offer to settle the refund claims. As a result of the settlement, Virginia Power decreased its unrecognized tax benefits by $8 million, and recognized a $2 million tax benefit, which impacted its effective tax rate. Also in connection with this settlement, Virginia Power realized interest income of $11 million, which is reflected in other income in the Consolidated Statements of Income. In 2016, Dominion Energy’s effective tax rate reflects a valuation allowance on a state credit not expected to be utilized by a Dominion Energy subsidiary which files a separate state return. The Companies’ deferred income taxes consist of the following: Dominion Energy Virginia Power Dominion Energy At December 31, 2018 2017 2018 2017 2018 2017 (millions) Deferred income taxes: Total deferred income tax assets $ 2,748 $ 2,686 $ 1,054 $ 923 $ 318 $ 320 Total deferred income tax liabilities 7,813 7,158 4,020 3,600 1,783 1,774 Total net deferred income tax liabilities $ 5,065 $ 4,472 $ 2,966 $2,677 $1,465 $ 1,454 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 4,933 $ 5,056 $ 3,367 $2,969 $1,170 $ 1,132 Excess deferred income taxes (993 ) (1,050 ) (678 ) (687 ) (254 ) (244 ) Nuclear decommissioning 815 829 273 260 — — Deferred state income taxes 626 834 284 378 175 227 Federal benefit of deferred state income taxes (132 ) (175 ) (60 ) (79 ) (37 ) (48 ) Deferred fuel, purchased energy and gas costs 60 1 59 (3 ) 1 2 Pension benefits 81 141 (132 ) (104 ) 431 419 Other postretirement benefits (5 ) (51 ) 55 44 (1 ) (2 ) Loss and credit carryforwards (1,546 ) (1,536 ) (183 ) (111 ) (7 ) (4 ) Valuation allowances 158 146 5 5 12 3 Partnership basis differences 1,135 473 — — 26 26 Other (67 ) (196 ) (24 ) 5 (51 ) (57 ) Total net deferred income tax liabilities $ 5,065 $ 4,472 $ 2,966 $2,677 $1,465 $ 1,454 Deferred Investment Tax Credits – Regulated Operations 51 51 51 51 — — Total Deferred Taxes and Deferred Investment Tax Credits $ 5,116 $ 4,523 $ 3,017 $2,728 $1,465 $ 1,454 The most significant impact reflected for the 2017 Tax Reform Act is the adjustment of the net accumulated deferred income tax liability for the reduction in the corporate income tax rate to 21%. In addition to amounts recognized in deferred income tax expense, the impacts of the 2017 Tax Reform Act decreased the accumulated deferred income tax liability by $3.1 billion at Dominion Energy, $1.9 billion at Virginia Power and $0.8 billion at Dominion Energy Gas at December 31, 2017. At Dominion Energy, the December 31, 2017 balance sheet reflected the impact of the 2017 Tax Reform Act on our regulatory liabilities which increased our regulatory liabilities by $4.2 billion, and created a corresponding deferred tax asset of $1.1 billion. At Virginia Power, our regulatory liabilities increased $2.6 billion, and created a deferred tax asset of $0.7 billion. At Dominion Energy Gas, our regulatory liabilities increased $1.0 billion, and created a deferred tax asset of $0.2 billion. These adjustments had no impact on 2017 cash flows. At December 31, 2018, Dominion Energy had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Federal losses $ 120 $ 25 $ — 2034 Federal investment credits — 1,007 — 2033-2038 Federal production credits — 150 — 2031-2038 Other federal credits — 62 — 2031-2038 State losses 1,126 73 (61 ) 2019-2038 State minimum tax credits — 122 — No expiration State investment and other credits — 107 (90 ) 2019-2025 Total $1,246 $ 1,546 $(151) At December 31, 2018, Virginia Power had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Federal losses $ 1 $ — $ — 2034 Federal investment credits — 113 — 2034-2038 Federal production and other credits — 61 — 2031-2038 State investment credits — 9 (5 ) 2024 Total $ 1 $183 $(5 ) At December 31, 2018, Dominion Energy Gas had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Other federal credits $ — $ 1 $ — 2032-2037 State losses 53 5 (5 ) 2036-2038 Total $ 53 $ 6 $ (5 ) A reconciliation of changes in the Companies’ unrecognized tax benefits follows: Dominion Energy Virginia Power Dominion Energy Gas 2018 2017 2016 2018 2017 2016 2018 2017 2016 (millions) Balance at January 1 $ 38 $ 64 $ 103 $ 4 $ 13 $ 12 $ — $ 7 $29 Increases-prior period positions 10 1 9 — — 4 — — 1 Decreases-prior period positions — (9 ) (44 ) — (1 ) (3 ) — — (19 ) Increases-current period positions 10 5 6 — — — — — — Settlements with tax authorities (6 ) (23 ) (8 ) (1 ) (8 ) — — (7 ) (4 ) Expiration of statutes of limitations (8 ) — (2 ) (1 ) — — — — — Balance at December 31 $ 44 $ 38 $ 64 $ 2 $ 4 $ 13 $— $ — $ 7 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 Energy and its subsidiaries, these unrecognized tax benefits were $37 million, $31 million and $45 million at December 31, 2018, 2017 and 2016, respectively. For Dominion Energy, the change in these unrecognized tax benefits increased income tax expense by $5 million in 2018 and decreased income tax expense by $9 million and $18 million in 2017 and 2016 respectively. For Virginia Power, these unrecognized tax benefits were $2 million, $3 million, and $9 million at December 31, 2018, 2017 and 2016, respectively. For Virginia Power, the change in these unrecognized tax benefits decreased income tax expense by $2 million and $6 million in 2018 and 2017, respectively, and increased income tax expense by $1 million in 2016. For Dominion Energy Gas, these unrecognized tax benefits were less than $1 million, at December 31, 2018 and 2017, and $5 million at December 31, 2016. For Dominion Energy Gas, the change in these unrecognized tax benefits decreased income tax expense by less than $1 million, $5 million, and $11 million in 2018, 2017, and 2016, respectively. Dominion Energy participates in the IRS Compliance Assurance Process which provides 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. In 2018, Dominion Energy submitted carryback claims for specified liability losses involving prior tax years. These claims will be subject to IRS examination. With the exception of these claims, the IRS has completed its audit of tax years through 2017. The statute of limitations has not yet expired for tax years after 2012. Although Dominion Energy has not received a final letter indicating no changes to its taxable income for tax year 2017, no material adjustments are expected. The IRS examination of tax year 2018 is ongoing. It is reasonably possible that settlement negotiations and expiration of statutes of limitations could result in a decrease in unrecognized tax benefits in 2019 by up to $18 million for Dominion Energy and less than $1 million for Virginia Power and Dominion Energy 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 $17 million for Dominion Energy and less than $1 million for Virginia Power and Dominion Energy Gas. Otherwise, with regard to 2018 and prior years, Dominion Energy, Virginia Power and Dominion Energy Gas cannot estimate the range of reasonably possible changes to unrecognized tax benefits that may occur in 2019. For each of the major states in which Dominion Energy operates, the earliest tax year remaining open for examination is as follows: State Earliest Pennsylvania (1) 2012 Connecticut 2015 Virginia (2) 2015 West Virginia (1) 2015 New York (1) 2011 Utah 2015 (1) Considered a major state for Dominion Energy 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 Energy utilizes operating losses or tax credits generated in years for which the statute of limitations has expired, such amounts are generally subject to examination.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	N OTE AIR ALUE 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 mid-point Inputs and Assumptions 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 industry publications, and to a lesser extent, broker quotes. When evaluating pricing information provided by Designated Contract Market settlement pricing, other pricing services, or brokers, the Companies consider the ability to transact at the quoted price, i.e. if the quotes are based on an active market or an inactive market and to the extent which pricing models are used, 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 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 sources. For options and contracts with option-like characteristics where observable pricing information is not available from external sources, Dominion Energy 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 Energy and Virginia Power use other option models under special circumstances, including but not limited to Spread Approximation Model and a Swing Option Model. 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 • Notional value • Credit enhancements • Time value For foreign currency derivative contracts: • Foreign currency forward exchange rates • Interest rates • Credit quality of counterparties and the Companies • Notional value • Credit enhancements • Time value For investments: • Quoted securities prices and indices • Securities trading information including volume and restrictions • Maturity • Interest rates • Credit quality 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, U.S. and international equity securities, mutual funds and certain Treasury securities held in nuclear decommissioning trust funds for Dominion Energy and Virginia Power, benefit plan trust funds for Dominion Energy and Dominion Energy Gas, and rabbi trust funds for Dominion Energy. • 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, foreign currency swaps and cash and cash equivalents, corporate debt instruments, government securities and other fixed income investments held in nuclear decommissioning trust funds for Dominion Energy and Virginia Power, benefit plan trust funds for Dominion Energy and Dominion Energy Gas and rabbi trust funds for Dominion Energy. • 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, certain natural gas and power options and other modeled commodity derivatives. 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. Alternative investments, consisting of investments in partnerships, joint ventures and other alternative investments held in nuclear decommissioning and benefit plan trust funds, 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. Alternative investments recorded at NAV are not classified in the fair value hierarchy. 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 Level 3 Valuations 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 mark-to-market The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at December 31, 2018. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility. Fair Value (millions) Valuation Techniques Unobservable Input Range Weighted (1) Assets Physical and financial forwards and futures: Natural gas (2) $42 Discounted cash flow Market price (per Dth) (3) (2) - 8 (1 ) FTRs 15 Discounted cash flow Market price (per MWh) (3) (2) - 7 1 Physical options: Natural gas 2 Option model Market price (per Dth) (3) 1 - 8 3 Price volatility (4) 18% - 73% 30 % Electricity 11 Option model Market price (per MWh) (3) 34 - 50 42 Price volatility (4) 39% - 60% 49 % Total assets $70 Liabilities Financial forwards: FTRs $ 6 Discounted cash flow Market price (per MWh) (3) (2) - 6 — Total liabilities $ 6 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) 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 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) Nonrecurring Fair Value Measurements D OMINION NERGY See Note 9 for information regarding an impairment charge recognized associated with Dominion Energy’s equity method investment in Fowler Ridge. A TLANTIC OAST IPELINE UARANTEE GREEMENT In October 2017, Dominion Energy entered into a guarantee agreement in connection with Atlantic Coast Pipeline’s obligation under a $3.4 billion revolving credit facility. See Note 22 for more information about the guarantee agreement associated with Atlantic Coast Pipeline’s revolving credit facility. Dominion Energy recorded a liability of $30 million, the fair value of the guarantee at inception, associated with the guarantee agreement. The fair value was estimated using a discounted cash flow method and is considered a Level 3 fair value measurement due to the use of a significant unobservable input related to the interest rate differential between the interest rate charged on the guaranteed revolving credit facility and the estimated interest rate that would have been charged had the loan not been guaranteed. D OMINION NERGY AS In the fourth quarter of 2018, subsequent to the announcement of the sale of Dominion Energy’s interest in Blue Racer, Dominion Energy Gas conducted a review of strategic alternatives of its remaining gathering and processing assets at DGP. Based on an evaluation of DGP’s long-lived assets for recoverability under a probability weighted approach, Dominion Energy Gas determined the assets were impaired. As a result of this evaluation, Dominion Energy Gas recorded a charge of $219 million ($165 million after-tax) 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 Energy and Dominion Energy Gas’ pension and other postretirement benefit plans are presented in Note 21. D OMINION NERGY The following table presents Dominion Energy’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) December 31, 2018 Assets Derivatives: Commodity $ — $ 180 $ 70 $ 250 Interest rate — 18 — 18 Foreign currency — 26 — 26 Investments (1) Equity securities: U.S. 3,277 — — 3,277 Fixed income: Corporate debt instruments — 431 — 431 Government securities 455 688 — 1,143 Cash equivalents and other 11 — — 11 Total assets $ 3,743 $ 1,343 $ 70 $ 5,156 Liabilities Derivatives: Commodity $ — $ 129 $ 6 $ 135 Interest rate — 142 — 142 Foreign currency — 2 — 2 Total liabilities $ — $ 273 $ 6 $ 279 December 31, 2017 Assets Derivatives: Commodity $ — $ 101 $157 $ 258 Interest rate — 17 — 17 Foreign currency — 32 — 32 Investments (1) Equity securities: U.S. 3,493 — — 3,493 Fixed income: Corporate debt instruments — 444 — 444 Government securities 307 794 — 1,101 Cash equivalents and other 34 — — 34 Total assets $ 3,834 $ 1,388 $157 $ 5,379 Liabilities Derivatives: Commodity $ — $ 190 $ 7 $ 197 Interest rate — 85 — 85 Foreign currency — 2 — 2 Total liabilities $ — $ 277 $ 7 $ 284 (1) Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $220 million and $88 million of assets at December 31, 2018 and 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. The following table presents the net change in Dominion Energy’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category: 2018 2017 2016 (millions) Balance at January 1, $ 150 $ 139 $ 95 Total realized and unrealized gains (losses): Included in earnings: Operating Revenue (2 ) 3 — Electric fuel and other energy-related purchases (15 ) (42 ) (35 ) Purchased gas — 1 — Included in other comprehensive income (loss) 1 (2 ) — Included in regulatory assets/liabilities (44 ) 42 (39 ) Settlements (27 ) 6 38 Purchases — — 87 Transfers out of Level 3 1 3 (7 ) Balance at December 31, $ 64 $ 150 $ 139 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: Operating Revenue $ — $ 2 $ — Electric fuel and other energy-related purchases — — (1 ) V IRGINIA OWER The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at December 31, 2018. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility. Fair Value Valuation Techniques Unobservable Input Range Weighted (1) Assets Physical and financial forwards and futures: Natural gas (2) $38 Discounted cash flow Market price (per Dth) (3) (2)-8 (1 ) FTRs 15 Discounted cash flow Market price (per MWh) (3) (2)-7 1 Physical options: Natural gas 2 Option model Market price (per Dth) (3) 1-8 3 Price volatility (4) 18%-73% 30 % Electricity 11 Option model Market price (per MWh) (3) 34-50 42 Price volatility (4) 39%-60% 49 % Total assets $66 Liabilities Financial forwards: FTRs $ 6 Discounted cash flow Market price (per MWh) (3) (2)-6 — Total liabilities $ 6 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents volatilities unrepresented in published markets. Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows: Significant Unobservable Position Change to Input Impact on Fair 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) 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) December 31, 2018 Assets Derivatives: Commodity $ — $ 24 $ 66 $ 90 Interest rate — 3 — 3 Investments (1) Equity securities: U.S. 1,476 — — 1,476 Fixed income: Corporate debt instruments — 221 — 221 Government securities 164 343 — 507 Total assets $ 1,640 $ 591 $ 66 $ 2,297 Liabilities Derivatives: Commodity $ — $ 9 $ 6 $ 15 Interest rate — 88 — 88 Total liabilities $ — $ 97 $ 6 $ 103 December 31, 2017 Assets Derivatives: Commodity $ — $ 14 $ 152 $ 166 Investments (1) Equity securities: U.S. 1,566 — — 1,566 Fixed income: Corporate debt instruments — 224 — 224 Government securities 168 326 — 494 Cash equivalents and other 16 — — 16 Total assets $ 1,750 $ 564 $ 152 $ 2,466 Liabilities Derivatives: Commodity $ — $ 4 $ 5 $ 9 Interest rate — 57 — 57 Total liabilities $ — $ 61 $ 5 $ 66 (1) Includes investments held in the nuclear decommissioning trusts. Excludes $160 million and $27 million of assets at December 31, 2018 and 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. 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: 2018 2017 2016 (millions) Balance at January 1, $ 147 $ 143 $ 93 Total realized and unrealized gains (losses): Included in earnings: Electric fuel and other energy-related purchases (17 ) (43 ) (35 ) Included in regulatory assets/liabilities (45 ) 40 (37 ) Settlements (25 ) 7 35 Purchases — — 87 Balance at December 31, $ 60 $ 147 $ 143 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, 2018, 2017 and 2016. D OMINION NERGY AS The following table presents Dominion Energy Gas’ assets and liabilities for 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) December 31, 2018 Assets Commodity $ — $ 3 $ — $ 3 Foreign currency — 26 — 26 Total assets $ — $29 $ — $29 Liabilities Interest rate $ — $17 $ — $17 Foreign currency — 2 — 2 Total liabilities $ — $19 $ — $19 December 31, 2017 Assets Foreign currency $ — $32 $ — $32 Total assets $ — $32 $ — $32 Liabilities Commodity $ — $ 4 $ 2 $ 6 Foreign currency — 2 — 2 Total liabilities $ — $ 6 $ 2 $ 8 The following table presents the net change in Dominion Energy Gas’ derivative assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category: 2018 2017 2016 (millions) Balance at January 1, $ (2 ) $ (2 ) $ 6 Total realized and unrealized gains (losses): Included in other comprehensive income (loss) 1 (3 ) — Transfers out of Level 3 1 3 (8 ) Balance at December 31, $ — $ (2 ) $ (2 ) There were no gains and losses included in earnings in the Level 3 fair value category for the years ended December 31, 2018, 2017 and 2016. 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, 2018, 2017 and 2016. 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, restricted cash and equivalents, customer and other receivables, affiliated 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: December 31, 2018 2017 Carrying Amount Estimated (1) Carrying Amount Estimated (1) (millions) Dominion Energy Long-term debt, including securities due within one year (2) $ 29,952 $31,045 $ 28,666 $31,233 Credit facility borrowings 73 73 — — Junior subordinated notes (3) 3,430 3,358 3,981 4,102 Remarketable subordinated notes (3) 1,386 1,340 1,379 1,446 Virginia Power Long-term debt, including securities due within one year (3) $ 11,671 $12,400 $ 11,346 $12,842 Dominion Energy Gas Long-term debt, including securities due within one year (4) $ 4,058 $ 4,072 $ 3,570 $ 3,719 (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 issuances 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 debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At December 31, 2018, and 2017, includes the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt of $(20) million and $(22) million, respectively. (3) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium. (4) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments.

Derivatives And Hedge Accountin

Derivatives And Hedge Accounting Activities	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives And Hedge Accounting Activities	N OTE ERIVATIVES ND EDGE CCOUNTING CTIVITIES See Note 2 for the Companies’ accounting policies, objectives, and strategies for using derivative instruments. 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 Energy’s derivative contracts include both over-the-counter over-the-counter Over-the-counter over-the-counter In general, most over-the-counter over-the-counter D OMINION NERGY Balance Sheet Presentation The tables below present Dominion Energy’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset Gross Amounts Not Offset Gross Assets (1) Financial Cash Net Gross Assets (1) Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 175 $ 12 $ — $ 163 $ 174 $ 9 $ — $ 165 Exchange 68 68 — — 80 80 — — Interest rate contracts: Over-the-counter 18 1 — 17 17 8 — 9 Foreign currency contracts: Over-the-counter 26 2 — 24 32 2 — 30 Total derivatives, subject to a master netting or similar arrangement $ 287 $ 83 $ — $ 204 $ 303 $ 99 $ — $ 204 (1) Excludes $7 million and $4 million of derivative assets at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements. December 31, 2018 December 31, 2017 Gross Amounts Not Balance Sheet Gross Amounts Not Balance Sheet Gross Liabilities (1) Financial Cash Net Gross Liabilities (1) Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 19 $ 12 $ — $ 7 $ 76 $ 9 $ 6 $ 61 Exchange 115 68 47 — 120 80 40 — Interest rate contracts: Over-the-counter 142 1 — 141 85 8 — 77 Foreign currency contracts: Over-the-counter 2 2 — — 2 2 — — Total derivatives, subject to a master netting or similar arrangement $ 278 $ 83 $ 47 $ 148 $ 283 $ 99 $ 46 $ 138 (1) Excludes $1 million of derivative liabilities at December 31, 2018 and 2017, which are not subject to master netting or similar arrangements. Volumes The following table presents the volume of Dominion Energy’s derivative activity as of December 31, 2018. 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) 56 27 Basis 214 557 Electricity (MWh): Fixed price (1) 11,101,869 1,537,200 FTRs 45,351,415 — Liquids (Gal) (2) 14,413,200 — Interest rate (3) $ 2,700,000,000 $ 3,915,839,913 Foreign currency (3)(4) $ — $ 280,000,000 (1) Includes options. (2) Includes NGLs and oil. (3) Maturity is determined based on final settlement period. (4) Euro equivalent volumes are € 250,000,000. Ineffectiveness and AOCI For the years ended December 31, 2018, 2017 and 2016, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness were immaterial. 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 Energy’s Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected to be After-Tax Maximum Term (millions) Commodities: Gas $ — $ 1 36 months Electricity 27 26 24 months Other 2 2 3 months Interest rate (276 ) (29 ) 396 months Foreign currency 12 (2 ) 90 months Total $(235 ) $ (2 ) The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., anticipated sales) in earnings, thereby achieving the realization of prices contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in market prices, interest rates and foreign currency exchange rates. Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – under Fair Value – not under Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ 55 $154 $ 209 Interest rate 14 — 14 Total current derivative assets (1) 69 154 223 Noncurrent Assets Commodity 6 35 41 Interest rate 4 — 4 Foreign currency 26 — 26 Total noncurrent derivative assets (2) 36 35 71 Total derivative assets $105 $189 $ 294 LIABILITIES Current Liabilities Commodity $ 17 $112 $ 129 Interest rate 26 — 26 Foreign currency 2 — 2 Total current derivative liabilities (3) 45 112 157 Noncurrent Liabilities Commodity 5 1 6 Interest rate 116 — 116 Total noncurrent derivative liabilities (4) 121 1 122 Total derivative liabilities $166 $113 $ 279 At December 31, 2017 ASSETS Current Assets Commodity $ 5 $158 $ 163 Interest rate 6 — 6 Total current derivative assets (1) 11 158 169 Noncurrent Assets Commodity — 95 95 Interest rate 11 — 11 Foreign currency 32 — 32 Total noncurrent derivative assets (2) 43 95 138 Total derivative assets $ 54 $253 $ 307 LIABILITIES Current Liabilities Commodity $103 $ 92 $ 195 Interest rate 53 — 53 Foreign currency 2 — 2 Total current derivative liabilities (3) 158 92 250 Noncurrent Liabilities Commodity 1 1 2 Interest rate 32 — 32 Total noncurrent derivative liabilities (4) 33 1 34 Total derivative liabilities $191 $ 93 $ 284 (1) Current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets. The following tables present the gains and losses on Dominion Energy’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 (Effective (1) Amount of Gain (Loss) Reclassified to Income Increase (2) (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (90 ) Electric fuel and other energy-related purchases 14 Total commodity $ 64 $(76 ) $ — Interest rate (3) (18 ) (48 ) 39 Foreign currency (4) (6 ) (13 ) — Total $ 40 $(137 ) $39 Year Ended December 31, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 81 Purchased gas (2 ) Total commodity $ 1 $ 79 $ — Interest rate (3) (8 ) (52 ) (58 ) Foreign currency (4) 18 20 — Total $ 11 $ 47 $(58 ) Year Ended December 31, 2016 Derivative type and location of gains (losses): Commodity: Operating revenue $330 Purchased gas (13 ) Electric fuel and other energy-related purchases (10 ) Total commodity $164 $307 $ — Interest rate (3) (66 ) (31 ) (26 ) Foreign currency (4) (6 ) (17 ) — Total $ 92 $259 $(26 ) (1) Amounts deferred into AOCI have no associated effect in Dominion Energy’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 Energy’s Consolidated Statements of Income. (3) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges. (4) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in other income. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in (1) Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $(28 ) $ 18 $ 2 Purchased gas 11 (3 ) 4 Electric fuel and other energy-related purchases (9 ) (59 ) (70 ) Other operations & maintenance — (1 ) 1 Total $(26 ) $(45 ) $(63 ) (1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion Energy’s Consolidated Statements of Income. V IRGINIA OWER Balance Sheet Presentation The tables below present Virginia Power’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets (1) Financial Cash Net Gross Assets (1) Financial Cash Collateral Net (millions) Commodity contracts: Over-the-counter $64 $ 6 $— $58 $155 $ 4 $— $151 Interest rate contracts: Over-the-counter 3 — — 3 — — — — Total derivatives, subject to a master netting or similar arrangement $67 $ 6 $— $61 $155 $ 4 $— $151 (1) Excludes $26 million and $11 million of derivative assets at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements. December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities (1) Financial Cash Net Gross Liabilities (1) Financial Cash Collateral Net (millions) Commodity contracts: Over-the-counter $ 6 $ 6 $— $— $ 4 $ 4 $— $ — Interest rate contracts: Over-the-counter 88 — — 88 57 — — 57 Total derivatives, subject to a master netting or similar arrangement $94 $ 6 $— $88 $61 $ 4 $— $57 (1) Excludes $9 million and $5 million of derivative liabilities at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements. Volumes The following table presents the volume of Virginia Power’s derivative activity at December 31, 2018. 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) 29 8 Basis 136 488 Electricity (MWh): Fixed price (1) 367,019 — FTRs 45,351,415 — Interest rate (2) $ 700,000,000 $ 1,200,000,000 (1) Includes options. (2) Maturity is determined based on final settlement period. Ineffectiveness and AOCI For the years ended December 31, 2018, 2017 and 2016, gains or losses on hedging instruments determined to be ineffective were immaterial. The following table presents selected information related to losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected to be Reclassified After-Tax Maximum (millions) Interest rate $ (13 ) $ (1 ) 396 months Total $ (13 ) $ (1 ) The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest payments) in earnings, thereby achieving the realization of interest rates contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in interest rates. Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Fair Value – Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ — $ 60 $ 60 Interest rate 3 — 3 Total current derivative assets (1) 3 60 63 Noncurrent Assets Commodity — 30 30 Total noncurrent derivative assets (2) — 30 30 Total derivative assets $ 3 $ 90 $ 93 LIABILITIES Current Liabilities Commodity $ — $ 15 $ 15 Interest rate 10 — 10 Total current derivative liabilities (3) 10 15 25 Noncurrent Liabilities Interest rate 78 — 78 Total noncurrent derivatives liabilities (4) 78 — 78 Total derivative liabilities $88 $ 15 $103 At December 31, 2017 ASSETS Current Assets Commodity $ — $ 75 $ 75 Total current derivative assets (1) — 75 75 Noncurrent Assets Commodity — 91 91 Total noncurrent derivative assets (2) — 91 91 Total derivative assets $ — $166 $166 LIABILITIES Current Liabilities Commodity $ — $ 9 $ 9 Interest rate 44 — 44 Total current derivative liabilities (3) 44 9 53 Noncurrent Liabilities Interest rate 13 — 13 Total noncurrent derivative liabilities (4) 13 — 13 Total derivative liabilities $57 $ 9 $ 66 (1) Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Virginia Power’s Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets. The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income: Derivatives in cash flow hedging Amount of (1) Amount of Increase (2) (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 2 $ (1 ) $ 39 Total $ 2 $ (1 ) $ 39 Year Ended December 31, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (8 ) $ (1 ) $ (58 ) Total $ (8 ) $ (1 ) $ (58 ) Year Ended December 31, 2016 Derivative type and location of gains (losses): Interest rate (3) $ (3 ) $ (1 ) $ (26 ) Total $ (3 ) $ (1 ) $ (26 ) (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 (1) Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity (2) $2 $(57) $(70) Total $2 $(57) $(70) (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. D OMINION NERGY AS Balance Sheet Presentation The tables below present Dominion Energy Gas’ derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Gross Amounts Not Offset in the Consolidated Gross Assets Financial Cash Net Gross Assets Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 3 $ — $ — $ 3 $ — $ — $ — $ — Foreign currency contracts: Over-the-counter 26 2 — 24 32 2 — 30 Total derivatives, subject to a master netting or similar arrangement $ 29 $ 2 $ — $ 27 $ 32 $ 2 $ — $ 30 December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Off set in the Consolidated Balance Sheet Gross Liabilities Financial Cash Net Gross Liabilities Financial Cash Net (millions) Commodity contracts Over-the-counter $ — $ — $ — $ — $ 6 $ — $ — $ 6 Interest rate contracts: Over-the-counter 17 — — 17 — — — — Foreign currency contracts: Over-the-counter 2 2 — — 2 2 — — Total derivatives, subject to a master netting or similar arrangement $ 19 $ 2 $ — $ 17 $ 8 $ 2 $ — $ 6 Volumes The following table presents the volume of Dominion Energy Gas’ derivative activity at December 31, 2018. 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) 14,413,200 — Interest rate (1) $ 300,000,000 $ 750,000,000 Foreign currency (1)(2) $ — $ 280,000,000 (1) Maturity is determined based on final settlement period. (2) Euro equivalent volumes are €250,000,000. Ineffectiveness and AOCI For the years ended December 31, 2018, 2017 and 2016, gains or losses on hedging instruments determined to be ineffective were immaterial. The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected After-Tax Maximum (millions) Commodities: NGLs $ 2 $ 2 3 months Interest rate (39 ) (4 ) 312 months Foreign currency 12 (2 ) 90 months Total $(25 ) $(4 ) The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., anticipated sales) in earnings, thereby achieving the realization of prices contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in market prices, interest rates, and foreign currency exchange rates. Fair Value and Gains and Losses on Derivative Instruments The following table presents the fair values of Dominion Energy Gas’ derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Fair Value – Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ 3 $— $ 3 Total current derivative assets (1) 3 — 3 Noncurrent Assets Foreign currency 26 — 26 Total noncurrent derivative assets (2) 26 — 26 Total derivative assets $29 $— $29 LIABILITIES Current Liabilities Interest rate $ 9 $— $ 9 Foreign currency 2 — 2 Total current derivative liabilities (3) 11 — 11 Noncurrent Liabilities Interest rate 8 — 8 Total noncurrent derivative liabilities (4) 8 — 8 Total derivative liabilities $19 $— $19 At December 31, 2017 ASSETS Noncurrent Assets Foreign currency $32 $— $32 Total noncurrent derivative assets (2) 32 — 32 Total derivative assets $32 $— $32 LIABILITIES Current Liabilities Commodity $ 6 $— $ 6 Foreign currency 2 — 2 Total current derivative liabilities (3) 8 — 8 Total derivative liabilities $ 8 $— $ 8 (1) Current derivative assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. The following tables present the gains and losses on Dominion Energy Gas’ derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income: Derivatives in cash flow hedging Amount of Gain Derivatives (1) Amount of (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (8 ) Total commodity $ 1 $ (8 ) Interest rate (2) (18 ) (6 ) Foreign currency (3) (6 ) (13 ) Total $(23 ) $(27 ) Year Ended December 31, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ (8 ) Total commodity $(10 ) $ (8 ) Interest rate (2) — (5 ) Foreign currency (3) 18 20 Total $ 8 $ 7 Year Ended December 31, 2016 Derivative type and location of gains (losses): Commodity: Operating revenue $ 4 Total commodity $(12 ) $ 4 Interest rate (2) (8 ) (2 ) Foreign currency (3) (6 ) (17 ) Total $(26 ) $(15 ) (1) Amounts deferred into AOCI have no associated effect in Dominion Energy Gas’ Consolidated Statements of Income. (2) Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in interest and related charges. (3) Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in other income. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity Operating revenue $(11 ) $— $1 Total $(11 ) $— $1

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Earnings Per Share	N OTE ARNINGS ER HARE The following table presents the calculation of Dominion Energy’s basic and diluted EPS: 2018 2017 2016 (millions, except EPS) Net Income Attributable to Dominion Energy $ 2,447 $ 2,999 $ 2,123 Average shares of common stock outstanding – Basic 654.2 636.0 616.4 Net effect of dilutive securities (1) 0.7 — 0.7 Average shares of common stock outstanding – Diluted 654.9 636.0 617.1 Earnings Per Common Share – Basic $ 3.74 $ 4.72 $ 3.44 Earnings Per Common Share – Diluted $ 3.74 $ 4.72 $ 3.44 (1) Dilutive securities for 2018 consist primarily of forward sale agreements, effective April 2018 to December 2018. Dilutive securities for 2016 consist primarily of the 2013 Equity Units. See Notes 17 and 19 for more information. The 2014 Equity Units were excluded from the calculation of diluted EPS for the year ended December 31, 2016 as the dilutive stock price threshold was not met. The 2016 Equity Units were excluded from the calculation of diluted EPS for the years ended December 31, 2018, 2017 and 2016, as the dilutive stock price threshold was not met. See Note 17 for more information. The Dominion Energy Midstream convertible preferred units were potentially dilutive securities but had no effect on the calculation of diluted EPS for the years ended December 31, 2018, 2017 and 2016. See Note 19 for more information.

Investments

Investments	12 Months Ended
	Dec. 31, 2018
Investments, Debt and Equity Securities [Abstract]
Investments	N OTE NVESTMENTS D OMINION NERGY Equity and Debt Securities R ABBI RUST ECURITIES Equity and debt securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled $111 million and $112 million at December 31, 2018 and 2017, respectively. D ECOMMISSIONING RUST ECURITIES Dominion Energy holds equity and debt securities, cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion Energy’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Fair (millions) December 31, 2018 Equity securities: (1) U.S. $1,741 $1,640 $(51) $3,330 Fixed income securities: (2) Corporate debt instruments 435 5 (9) 431 Government securities 1,092 17 (12) 1,097 Common/collective trust funds 76 — — 76 Cash equivalents and other (3) 4 — — 4 Total $3,348 $1,662 $(72) (4) $4,938 December 31, 2017 Equity securities: (2) U.S. $1,569 $1,857 $ — $3,426 Fixed income securities: (2) Corporate debt instruments 430 15 (1) 444 Government securities 1,039 27 (5) 1,061 Common/collective trust funds 60 — — 60 Cost method investments 68 — — 68 Cash equivalents and other (3) 34 — — 34 Total $3,200 $1,899 $ (6) (4) $5,093 (1) Effective January 2018, unrealized gains and losses on equity securities, including those previously classified as cost method investments, are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on equity securities (for 2017) and fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (3) Includes pending sales of securities of $5 million at December 31, 2017. (4) The fair value of securities in an unrealized loss position was $833 million and $565 million at December 31, 2018 and 2017, respectively. The portion of unrealized gains and losses that relates to equity securities held within Dominion Energy’s nuclear decommissioning trusts is summarized below: Twelve (millions) Net losses recognized during the period $ (245 ) Less: Net gains recognized during the period on securities sold during the period (58 ) Unrealized losses recognized during the period on securities still held at December 31, 2018 (1) $ (303 ) (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. The fair value of Dominion Energy’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 167 Due after one year through five years 389 Due after five years through ten years 376 Due after ten years 672 Total $ 1,604 Presented below is selected information regarding Dominion Energy’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2018 2017 2016 (millions) Proceeds from sales $ 1,804 $ 1,831 $ 1,422 Realized gains (1) 140 166 128 Realized losses (1) 91 71 55 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2. Dominion Energy recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows: Year Ended December 31, 2018 2017 2016 (millions) Total other-than-temporary impairment losses (1) $ 30 $ 44 $ 51 Losses recorded to the nuclear decommissioning trust regulatory liability — (16 ) (16 ) Losses recognized in other comprehensive income (before taxes) (30 ) (5 ) (12 ) Net impairment losses recognized in earnings $ — $ 23 $ 23 (1) Amounts include other-than-temporary impairment losses for debt securities of $5 million and $13 million at December 31, 2017 and 2016, respectively. V IRGINIA OWER Virginia Power holds equity and debt securities, 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 Total Unrealized Losses Fair Value (millions) December 31, 2018 Equity securities: (1) U.S. $858 $751 $(24 ) $1,585 Fixed income securities: (2) Corporate debt instruments 224 2 (5 ) 221 Government securities 504 7 (5 ) 506 Common/collective trust funds 51 — — 51 Cash equivalents and other (3) 6 — — 6 Total $1,643 $760 $(34) (4) $2,369 December 31, 2017 Equity securities: (2) U.S. $ 734 $831 $— $1,565 Fixed income securities: (2) Corporate debt instruments 216 8 — 224 Government securities 482 13 (2 ) 493 Common/collective trust funds 27 — — 27 Cost method investments 68 — — 68 Cash equivalents and other (3) 22 — — 22 Total $1,549 $852 $(2 ) (4) $2,399 (1) Effective January 2018, unrealized gains and losses on equity securities, including those previously classified as cost method investments, are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on equity securities (for 2017) and fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (3) Includes pending sales of securities of $6 million at both December 31, 2018 and 2017. (4) The fair value of securities in an unrealized loss position was $404 million and $234 million at December 31, 2018 and 2017, respectively. The portion of unrealized gains and losses that relates to equity securities held within Virginia Power’s nuclear decommissioning trusts is summarized below: Twelve (millions) Net losses recognized during the period $ (105 ) Less: Net gains recognized during the period on securities sold during the period (32 ) Unrealized losses recognized during the period on securities still held at December 31, 2018 (1) $ (137 ) (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. The fair value of Virginia Power’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2018, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 54 Due after one year through five years 156 Due after five years through ten years 210 Due after ten years 358 Total $ 778 Presented below is selected information regarding Virginia Power’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2018 2017 2016 (millions) Proceeds from sales $ 887 $ 849 $ 733 Realized gains (1) 60 75 63 Realized losses (1) 27 30 27 (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, 2018 2017 2016 (millions) Total other-than-temporary impairment losses (1) $ 15 $ 20 $ 26 Losses recorded to the nuclear decommissioning trust regulatory liability — (16 ) (16 ) Losses recognized in other comprehensive income (before taxes) (15 ) (2 ) (7 ) Net impairment losses recognized in earnings $ — $ 2 $ 3 (1) Amounts include other-than-temporary impairment losses for debt securities of $2 million and $8 million at December 31, 2017 and 2016 , respectively. Equity Method Investments D OMINION NERGY AND OMINION NERGY AS Investments that Dominion Energy and Dominion Energy Gas account for under the equity method of accounting are as follows: Company Ownership% Investment Description As of December 31, 2018 2017 (millions) Dominion Energy Atlantic Coast Pipeline 48 % $ 820 $ 382 Gas transmission system Blue Racer 50 % — 691 Midstream gas and related services Iroquois 50 % (1) 302 311 Gas transmission system Fowler Ridge 50 % 82 81 Wind-powered merchant generation facility Other (2) various 74 79 Total $ 1,278 $ 1,544 Dominion Energy Gas Iroquois 24.07 % $ 91 $ 95 Gas transmission system Total $ 91 $ 95 (1) Comprised of Dominion Energy Midstream’s interest of 25.93% and Dominion Energy Gas’ interest of 24.07%. See Note 15 for more information. (2) Liability of less than $1 million and $17 million associated with NedPower recorded to other deferred credits and other liabilities, on the Consolidated Balance Sheets as of December 31, 2018 and 2017, respectively. See additional discussion of NedPower below. Dominion Energy’s equity earnings on its investments totaled $197 million, $14 million and $111 million in 2018, 2017 and 2016, respectively, included in other income in Dominion Energy’s Consolidated Statements of Income. Dominion Energy received distributions from these investments of $209 million, $419 million and $104 million in 2018, 2017 and 2016, respectively. As of December 31, 2018 and 2017, the carrying amount of Dominion Energy’s investments exceeded its share of underlying equity in net assets by $161 million and $249 million, respectively. At December 31, 2018 these differences are comprised of $146 million of equity method goodwill that is not being amortized and $15 million related to basis differences from Dominion Energy’s investments in wind projects, which are being amortized over the useful lives of the underlying assets, and in Atlantic Coast Pipeline, which is being amortized over the term of its credit facility. At December 31, 2017 these differences are comprised of $176 million of equity method goodwill and $73 million related to basis differences from Dominion Energy’s investments in Blue Racer and wind projects, and in Atlantic Coast Pipeline. Dominion Energy Gas’ equity earnings on its investment totaled $24 million in 2018 and $21 million in 2017 and 2016. Dominion Energy Gas received distributions from its investment of $28 million, $24 million and $22 million in 2018, 2017 and 2016, respectively. As of December 31, 2018 and 2017, the carrying amount of Dominion Energy 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. In May 2016, Dominion Energy Gas sold 0.65% of the noncontrolling partnership interest in Iroquois to TransCanada for approximately $7 million, which resulted in a $5 million ($3 million after-tax) D OMINION NERGY A TLANTIC OAST IPELINE In September 2014, Dominion Energy, along with Duke and Southern Company Gas, announced the formation of Atlantic Coast Pipeline. The Atlantic Coast Pipeline partnership agreement includes provisions to allow Dominion Energy an option to purchase additional ownership interest in Atlantic Coast Pipeline to maintain a leading ownership percentage. In October 2016, Dominion Energy purchased an additional 3% membership interest in Atlantic Coast Pipeline from Duke for $14 million. As of December 31, 2018, the members hold the following membership interests: Dominion Energy, 48%; Duke, 47%; and Southern Company Gas, 5%. Atlantic Coast Pipeline is focused on constructing an approximately 600-mile 20-year DETI provides services to Atlantic Coast Pipeline which totaled $203 million, $129 million and $95 million in 2018, 2017 and 2016, respectively, included in operating revenue in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income. Amounts receivable related to these services were $13 million and $12 million at December 31, 2018 and 2017, respectively, composed entirely of accrued unbilled revenue, included in other receivables in Dominion Energy and Dominion Energy Gas’ Consolidated Balance Sheets. In October 2017, Dominion Energy entered into a guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under its credit facility. See Note 22 for more information. Dominion Energy contributed $414 million, $310 million and $184 million during 2018, 2017 and 2016, respectively, to Atlantic Coast Pipeline. Dominion Energy received distributions of $36 million and $270 million during 2018 and 2017, respectively, from Atlantic Coast Pipeline. No distributions were received in 2016. During the third and fourth quarters of 2018, a FERC stop work order together with delays in obtaining permits necessary for construction along with construction delays due to judicial actions impacted the cost and schedule for the project. As a result project cost estimates have increased from between $6.0 billion to $6.5 billion to between $7.0 billion to $7.5 billion, excluding financing costs. Atlantic Coast Pipeline expects to achieve a late 2020 in-service date for at least key segments of the project, while the remainder may extend into early 2021. Alternatively, if it takes longer to resolve the judicial issues, such as through appeal to the Supreme Court of the U.S., full in-service could extend to the end of 2021 with total project cost estimated to increase an additional $250 million, resulting in total project cost estimates of $7.25 billion to $7.75 billion excluding financing costs. Abnormal weather, work delays (including due to judicial or regulatory action) and other conditions may result in further cost or schedule modifications in the future, which could result in a material impact to Dominion Energy’s cash flows, financial position and/or results of operations. B LUE ACER In December 2012, Dominion Energy 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 was an equal partnership between Dominion Energy and Caiman, with Dominion Energy contributing midstream assets and Caiman contributing private equity capital. In December 2016, Dominion Energy Gas repurchased a portion of the Western System from Blue Racer for $10 million. In December 2018, Dominion Energy sold its 50% limited partnership interest in Blue Racer for up-front after-tax), F OWLER IDGE ED OWER In the fourth quarter of 2017, Dominion Energy recorded a charge of $126 million ($76 million after-tax) As a result of the impairment recorded by NedPower, Dominion Energy evaluated its equity method investment in Fowler Ridge, a similar wind-powered merchant generation facility, determined its fair value was other than-temporarily impaired and recorded an impairment charge of $32 million ($20 million after-tax) O THER ATALYST LD IVER YDROELECTRIC IMITED ARTNERSHIP In September 2018, Dominion Energy completed the sale of its 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership and received proceeds of $91 million. The sale resulted in a gain of $87 million ($63 million after-tax),

Property Plant And Equipment

Property Plant And Equipment	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
Property Plant And Equipment	N OTE ROPERTY LANT AND QUIPMENT Major classes of property, plant and equipment and their respective balances for the Companies are as follows: At December 31, 2018 2017 (millions) Dominion Energy Utility: Generation $ 19,250 $ 17,602 Transmission 16,669 15,335 Distribution 18,549 17,408 Storage 2,905 2,887 Nuclear fuel 1,626 1,599 Gas gathering and processing 307 219 Oil and gas 1,763 1,720 General and other 1,476 1,514 Plant under construction 2,385 7,765 Total utility 64,930 66,049 Nonutility: Merchant generation-nuclear 1,550 1,452 Merchant generation-other 3,802 4,992 Nuclear fuel 1,025 968 Gas gathering and processing 185 630 LNG facility 3,977 — Other-including plant under construction 1,109 732 Total nonutility 11,648 8,774 Total property, plant and equipment $ 76,578 $ 74,823 Virginia Power Utility: Generation $ 19,250 $ 17,602 Transmission 9,392 8,332 Distribution 11,785 11,151 Nuclear fuel 1,626 1,599 General and other 821 794 Plant under construction 1,639 2,840 Total utility 44,513 42,318 Nonutility-other 11 11 Total property, plant and equipment $ 44,524 $ 42,329 Dominion Energy Gas Utility: Transmission $ 4,758 $ 4,732 Distribution 3,527 3,267 Storage 1,691 1,688 Gas gathering and processing 210 202 General and other 233 216 Plant under construction 494 293 Total utility 10,913 10,398 Nonutility: Gas gathering and processing 185 630 Other-including plant under construction 140 145 Total nonutility 325 775 Total property, plant and equipment $ 11,238 $ 11,173 Jointly-Owned Power Stations Dominion Energy and Virginia Power’s proportionate share of jointly-owned power stations at December 31, 2018 is as follows: Bath (1) North (1) Clover (1) Millstone (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % Plant in service 1,058 2,560 590 1,231 Accumulated depreciation (639 ) (1,305 ) (240 ) (400 ) Nuclear fuel — 721 — 571 Accumulated amortization of nuclear fuel — (608 ) — (423 ) Plant under construction 6 103 9 66 (1) Units jointly owned by Virginia Power. (2) Unit jointly owned by Dominion Energy. The co-owners Sale of Certain Retail Energy Marketing Assets In October 2017, Dominion Energy entered into an agreement to sell certain assets associated with its nonregulated retail energy marketing operations for total consideration of $143 million, subject to customary approvals and certain adjustments. In December 2017, the first phase of the agreement closed for $79 million, which resulted in the recognition of a $78 million ($48 million after-tax) after-tax) ten-year Sale of Certain Merchant Generation Facilities In December 2018, Dominion Energy completed the sale of Fairless and Manchester for total consideration of $1.2 billion, subject to customary closing adjustments. Dominion Energy recognized a gain of $210 million ($198 million after-tax) more-likely-than-not Acquisition of Solar Projects In September 2017, Virginia Power entered into agreements to acquire two solar development projects in North Carolina. The first acquisition closed in October 2018. The facility commenced commercial operations in December 2018 at a cost of $140 million, including the initial acquisition cost. The second acquisition is expected to close prior to the project commencing commercial operations, which is expected by the end of 2019, and cost approximately $140 million once constructed, including the initial acquisition cost. The projects are expected to generate approximately 155 MW combined. Virginia Power anticipates claiming federal investment tax credits on these solar projects. In February 2019, Virginia Power completed the acquisition of a solar development project in Virginia. The project is expected to commence commercial operations in the first quarter 2019, and cost approximately $37 million once constructed, including the initial acquisition cost. The project is expected to generate approximately 20 MW. Virginia Power anticipates claiming federal investment tax credits on this solar project. In August 2018, Virginia Power entered into agreements to acquire two solar development projects in North Carolina and Virginia. The first acquisition is expected to close prior to the project commencing commercial operations, which is expected by the end of 2019, and cost approximately $120 million once constructed, including the initial acquisition cost. The second acquisition is expected to close prior to the project commencing commercial operations, which is expected by the end of 2020, and cost approximately $130 million, including the initial acquisition cost. The projects are expected to generate approximately 155 MW combined. Virginia Power anticipates claiming federal investment tax credits on these solar projects. Assignment of Tower Rental Portfolio Virginia Power rents space on certain of its electric transmission towers to various wireless carriers for communications antennas and other equipment. In March 2017, Virginia Power sold its rental portfolio to Vertical Bridge Towers II, LLC for $91 million in cash. The proceeds are subject to Virginia Power’s FERC-regulated tariff, under which it is required to return half of the proceeds to customers. Virginia Power recorded $6 million in operating revenue and $11 million in other income during 2018 and 2017, respectively, with $29 million remaining to be recognized ratably through 2023. Assignments of Shale Development Rights In December 2013, Dominion Energy 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 provided for payments to Dominion Energy 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 Energy Gas received approximately $100 million in cash proceeds. In 2014, Dominion Energy Gas received $16 million in additional cash proceeds resulting from post-closing adjustments. In March 2015, Dominion Energy 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 after-tax) after-tax) after-tax) after-tax) after-tax) In November 2014, Dominion Energy 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 provided for payments to Dominion Energy 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 Energy Gas closed on the agreement and received proceeds of $60 million associated with an initial conveyance of approximately 12,000 acres. In connection with that agreement, in 2016, Dominion Energy Gas conveyed a 50% interest in approximately 4,000 acres of Marcellus Shale development rights and received proceeds of $10 million and an overriding royalty interest in gas produced from the acreage. These transactions resulted in a $10 million ($6 million after-tax) after-tax) after-tax) In March 2018, Dominion Energy Gas closed an agreement with a natural gas producer to convey approximately 11,000 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 Energy Gas, subject to customary adjustments, of $16 million. In March 2018, Dominion Energy Gas received cash proceeds of $16 million associated with the conveyance of the acreage, resulting in a $16 million ($12 million after-tax) In June 2018, Dominion Energy Gas closed an amendment to an agreement with a natural gas producer for the elimination of Dominion Energy Gas’ overriding royalty interest in gas produced from approximately 9,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields previously conveyed in December 2013. In June 2018, Dominion Energy Gas received proceeds of $6 million associated with the transaction, resulting in a $6 million ($4 million after-tax)

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	N OTE OODWILL AND NTANGIBLE SSETS Goodwill The changes in Dominion Energy and Dominion Energy Gas’ carrying amount and segment allocation of goodwill are presented below: Power Generation Gas Infrastructure Power Delivery Corporate and (1) Total (millions) Dominion Energy Balance at December 31, 2016 (2) $ 1,422 $ 4,051 $ 926 $ — $ 6,399 Dominion Energy Questar Combination — 6 (3 ) — — 6 Balance at December 31, 2017 (2) $ 1,422 $ 4,057 $ 926 $ — $ 6,405 Purchase Accounting Adjustment — 5 — — 5 Balance at December 31, 2018 (2) $ 1,422 $ 4,062 $ 926 $ — $ 6,410 Dominion Energy Gas Balance at December 31, 2016 (2) $ — $ 542 $ — $ — $ 542 No events affecting goodwill — — — — — Balance at December 31, 2017 (2) $ — $ 542 $ — $ — $ 542 Purchase Accounting Adjustment — 5 — — 5 Balance at December 31, 2018 (2) $ — $ 547 $ — $ — $ 547 (1) Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes. (2) Goodwill amounts do not contain any accumulated impairment losses. (3) See Note 3. Other Intangible Assets The Companies’ other intangible assets are subject to amortization over their estimated useful lives. Dominion Energy’s amortization expense for intangible assets was $82 million, $80 million and $73 million for 2018, 2017 and 2016, respectively. In 2018, Dominion Energy acquired $127 million of intangible assets, primarily representing software and right-of-use right-of-use 2018 2017 At December 31, Gross Accumulated Gross Accumulated (millions) Dominion Energy Software, licenses and other $ 1,033 $ 363 $ 1,043 $ 358 Virginia Power Software, licenses and other $ 384 $ 134 $ 347 $ 114 Dominion Energy Gas Software, licenses and other $ 174 $ 65 $ 165 $ 56 Annual amortization expense for these intangible assets is estimated to be as follows: 2019 2020 2021 2022 2023 (millions) Dominion Energy $ 67 $ 56 $ 44 $ 34 $ 23 Virginia Power $ 29 $ 23 $ 16 $ 12 $ 6 Dominion Energy Gas $ 14 $ 13 $ 12 $ 8 $ 7

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2018
Regulated Operations [Abstract]
Regulatory Assets and Liabilities	N OTE EGULATORY SSETS ND IABILITIES Regulatory assets and liabilities include the following: At December 31, 2018 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 96 70 Deferred nuclear refueling outage costs (3) 69 54 Unrecovered gas costs (4) 14 38 Other 143 109 Regulatory assets-current 496 294 Unrecognized pension and other postretirement benefit costs (5) 1,497 1,336 Deferred rate adjustment clause costs (2) 329 401 Utility reform legislation (6) 204 147 PJM transmission rates (7) 192 222 Derivatives (8) 184 223 Deferred cost of fuel used in electric generation (1) 83 — Other 187 151 Regulatory assets-noncurrent 2,676 2,480 Total regulatory assets $ 3,172 $ 2,774 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 117 $ 101 Cost-of-service (10) 104 — Reserve for rate credits to electric utility customers (11) 71 — Other 64 92 Regulatory liabilities-current (12) 356 193 Income taxes refundable through future rates (13) 4,071 4,058 Provision for future cost of removal and AROs (9) 1,409 1,384 Nuclear decommissioning trust (14) 1,070 1,121 Derivatives ( 8 ) 25 69 Other 265 284 Regulatory liabilities-noncurrent 6,840 6,916 Total regulatory liabilities $ 7,196 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 78 56 Deferred nuclear refueling outage costs (3) 69 54 Other 103 72 Regulatory assets-current 424 205 Deferred rate adjustment clause costs (2) 230 312 PJM transmission rates (7) 192 222 Derivatives (8) 151 190 Deferred cost of fuel used in electric generation (1) 83 — Other 81 86 Regulatory assets-noncurrent 737 810 Total regulatory assets $ 1,161 $ 1,015 Regulatory liabilities: Cost-of-service (10) $ 95 $ — Provision for future cost of removal (9) 92 80 Reserve for rate credits to customers (11) 71 — Other 41 47 Regulatory liabilities-current 299 127 Income taxes refundable through future rates (13) 2,579 2,581 Nuclear decommissioning trust (14) 1,070 1,121 Provision for future cost of removal (9) 940 915 Derivatives ( 8 ) 25 69 Other 33 74 Regulatory liabilities-noncurrent 4,647 4,760 Total regulatory liabilities $ 4,946 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 18 $ 14 Unrecovered gas costs (4) 9 8 Other 2 4 Regulatory assets-current (16) 29 26 Unrecognized pension and other postretirement benefit costs (5) 392 258 Utility reform legislation (6) 204 147 Deferred rate adjustment clause costs (2) 99 89 Other 32 17 Regulatory assets-noncurrent 727 511 Total regulatory assets $ 756 $ 537 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 14 $ 13 PIPP (15) 3 20 Other 4 5 Regulatory liabilities-current (12) 21 38 Income taxes refundable through future rates (13) 1,011 998 Provision for future cost of removal and AROs (9) 158 160 Cost-of-service (10) 19 — Other 97 69 Regulatory liabilities-noncurrent 1,285 1,227 Total regulatory liabilities $ 1,306 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. See Note 13 for more information. (2) Primarily reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power and deferrals of costs associated with certain current and prospective rider projects for Dominion Energy 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 or overrecovered gas costs at regulated gas operations, which are recovered or refunded 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 Energy and Dominion Energy Gas’ rate-regulated subsidiaries. (6) Ohio legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date (7) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (10) Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at the Companies’ regulated electric generation and electric and natural gas distribution operations. See Note 13 for more information. (11) Charge associated with Virginia legislation enacted in March 2018 that requires one-time (12) Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas’ Consolidated Balance Sheets. (13) Amounts recorded to pass the effect of reduced income tax rates from the 2017 Tax Reform Act to customers in future periods, which will reverse at the weighted average tax rate that was used to build the reserves over the remaining book life of the property, net of amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity. (14) 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. (15) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information. (16) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. At December 31, 2018, $396 million of Dominion Energy’s, $300 million of Virginia Power’s and $12 million of Dominion Energy Gas’ regulatory assets represented past expenditures on which they do not currently earn a return. With the exception of the PJM transmission cost allocation matter, the majority of these expenditures are expected to be recovered within the next two years.

Regulatory Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2018
Regulated Operations [Abstract]
Regulatory Matters	N OTE EGULATORY 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 regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that 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 —E LECTRIC Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public util-ities. Virginia Power purchases and sells electricity in the PJM wholesale market and sells electricity to wholesale purchasers in Virginia and North Carolina. Dominion Energy’s merchant generators sell electricity in the PJM, CAISO and ISO-NE 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 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 investment in electric transmission infrastructure. In March 2010, ODEC and North Carolina Electric Membership Corporation filed a complaint with FERC against Virginia Power claiming, among other issues, that the incremental costs of undergrounding certain transmission line projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power’s transmission formula rate. A settlement of the other issues raised in the complaint was approved by FERC in May 2012. 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 In October 2017, FERC issued an order determining the calculation of the incremental costs of undergrounding the transmission projects and affirming that the costs are to be recovered from the wholesale transmission customers with loads located in Virginia. FERC directed Virginia Power to rebill all wholesale transmission customers retroactively to March 2010 within 30 days of when the proceeding becomes final and no longer subject to rehearing. In November 2017, Virginia Power, North Carolina Electric Membership Corporation and the wholesale transmission customers filed petitions for rehearing. In July 2018, FERC denied the rehearing requests related to the October 2017 order determining the calculation of the undergrounding costs. Several parties have appealed FERC’s decision to the U.S. Court of Appeals for the D.C. Circuit. This matter is pending. While Virginia Power cannot predict the outcome of the matter, it is not expected to have a material effect on results of operations. In January 2019, FERC issued an order denying PJM’s request to waive certain provisions of the PJM Tariff regarding the liquidation of a portfolio of FTRs owned by GreenHat who had defaulted on its financial obligations. As a result of FERC’s order, PJM is required to use the existing tariff provisions to liquidate GreenHat’s FTR portfolio and allocate the resulting costs to PJM members. In February 2019, PJM filed a request for clarification and rehearing with FERC. While the impacts of this order could be material to 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. 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 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. In June 2016, PJM, the PJM transmission owners and state commissions representing substantially all of the load in the PJM market submitted a settlement to FERC to resolve the outstanding issues regarding this matter. In May 2018, FERC issued an order accepting the settlement agreement and directed PJM to make a compliance filing with revised tariff records. As a result, in August 2018, Virginia Power began to make payments to PJM, to continue for the next 10 years totaling $276 million, under the terms of revised tariff records, which was partially offset by a $265 million regulatory asset for the amount that will be recovered through retail rates in Virginia. At December 31, 2018, Virginia Power’s Consolidated Balance Sheet includes $126 million in other current liabilities and $50 million included in other deferred credits and other liabilities for amounts owed to PJM. FERC—G AS In July 2017, FERC audit staff communicated to DETI that it had substantially completed an audit of DETI’s compliance with the accounting and reporting requirements of FERC’s Uniform System of Accounts and provided a description of matters and preliminary recommendations. In November 2017, the FERC audit staff issued its audit report which could have the potential to result in adjustments which could be material to Dominion Energy and Dominion Energy Gas’ results of operations. In December 2017, DETI provided its response to the audit report. DETI requested FERC review of contested findings and submitted its plan for compliance with the uncontested portions of the report. In connection with one uncontested issue, DETI recognized a charge of $15 million ($9 million after-tax) write-off after-tax) 2017 T AX EFORM CT Subsequent to the enactment of the 2017 Tax Reform Act, the Companies’ state regulators issued orders requesting that public utilities evaluate the total tax impact on the entity’s cost of service and accrue a regulatory liability attributable to the benefits of the reduction in the corporate income tax rate. Certain of the orders requested that the public utilities submit a response to the state regulatory commissions detailing the total tax impact on the utility’s cost of service. The Companies began to reserve the impacts of the cost-of-service In September 2018, the Virginia Commission issued an order directing Virginia Power to submit a filing quantifying the impacts of the 2017 Tax Reform Act in advance of the April 1, 2019 implementation as required by legislation. In October 2018, Virginia Power filed testimony with the Virginia Commission to implement adjustments in its base rates reflecting actual annual reductions in corporate income taxes resulting from the 2017 Tax Reform Act, which included a proposed annual revenue reduction of approximately $151 million effective April 2019. In December 2018, the Staff of the Virginia Commission proposed an annual revenue reduction of approximately $190 million. In January 2019, Virginia Power filed updated testimony with a proposed annual revenue reduction of approximately $171 million. Additionally, Virginia Power proposed to issue a one-time true-up one-time 15-month In August 2018, Virginia Power filed with FERC to waive protocols and begin reflecting projected tax reform benefits of approximately $100 million through the transmission formula rate prior to the normal formula rate process. FERC granted the waiver and the amounts began being reflected in customer billings in November 2018 reflecting the adjustment effective January 1, 2018. In October 2018, the North Carolina Commission issued an order requesting companies file to reduce base rates expeditiously. Virginia Power made its compliance filing in October 2018 and submitted an annual base rate revenue decrease of approximately $14 million effective in early 2019. Virginia Power also proposed to issue a one-time In May 2018, the Utah Commission approved a stipulation submitted by Questar Gas proposing the cost-of-service one-year In October 2018, the Ohio Commission issued an order requiring rate-regulated utilities to file an application reflecting the impact of the 2017 Tax Reform Act on current rates by January 1, 2019. In December 2018, East Ohio filed its application proposing an approach to establishing rates and charges by and through which to return tax reform benefits to its customers. This case is pending. As directed by the West Virginia Commission, Hope is utilizing regulatory accounting to track the effects of the 2017 Tax Reform Act beginning in January 2018 and submitted testimony in July 2018 detailing such effects. In August 2018, the West Virginia Commission approved a settlement implementing base rate reductions effective September 1, 2018. In November 2018, the West Virginia Commission issued an order requiring Hope to file a calculation of prospective tax reform savings based on 2017 financial statements, using federal income tax rates reduced for consolidated tax savings, and to record as a regulatory liability the difference between the amount calculated based on 2017 financial statements and the amount included in the voluntary base rate reduction effective September 1, 2018. In December 2018, Hope filed the required calculation setting forth an annual regulatory liability deferral amount of $0.4 million. The disposition of the additional regulatory liability will be determined in a future rate proceeding. These reductions are not expected to have a material impact on Hope’s financial condition. In March 2018, FERC announced actions to address the income tax allowance component of regulated entities’ cost-of-service one-time cost-of-service In July 2018, FERC issued a final rule adopting and modifying the procedures for determining whether jurisdictional natural gas pipelines may be collecting unjust and unreasonable rates in light of the reduction in the corporate income tax rate. Specifically, this final rule does not require master limited partnerships to eliminate their income tax allowances when completing the informational filing and allows entities that are wholly-owned by corporations to include an income tax allowance. During 2018, Dominion Energy’s FERC-regulated pipelines, including those accounted for as equity method investments, filed the required informational reports with FERC. Dominion Energy Overthrust Pipeline, LLC, White River Hub, Dominion Energy Questar Pipeline and Cove Point have reached resolution through settlement, which did not result in a material impact to results of operations, financial condition and/or cash flows of Dominion Energy, waiver or FERC terminating the 501-G proceeding. In January 2019, Iroquois reached a settlement in principle with its customers, which if approved would not have a material impact to Dominion Energy or Dominion Energy Gas, and expects to file a settlement agreement with FERC in the first quarter of 2019. The FERC dockets for DETI and DECG remain open. While the informational filings for these two pipelines indicated that no changes to current rates charged to customers were necessary, given the associated uncertainty, Dominion Energy and Dominion Energy Gas are currently unable to predict the outcome of these matters; however, any change in rates permitted to be charged to customers could have a material impact on results of operations, financial condition and/or cash flows. Other Regulatory Matters V IRGINIA EGULATION The Regulation Act enacted in 2007 instituted a cost-of-service 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, renewable energy programs and nuclear license renewals, 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. Grid Transformation and Security Act of 2018 In March 2018, the GTSA reinstated base rate reviews on a triennial basis, other than the first review which will be a quadrennial review, occurring for Virginia Power in 2021 for the four successive 12-month In the triennial review proceedings, earnings that are more than 70 basis points above the utility’s authorized return on equity that might have been refunded to customers and served as the basis for a reduction in future rates, may be reduced by approved investment amounts in qualifying solar or wind generation facilities or electric distribution grid transformation projects that Virginia Power elects to include in a customer credit reinvestment offset. The legislation declares that electric distribution grid transformation projects are in the public interest and provides that the costs of such projects may be recovered through a rate adjustment clause if not the subject of a customer credit reinvestment offset. Any costs that are the subject of a customer credit reinvestment offset may not be recovered in base rates for the service life of the projects and may not be included in base rates in future triennial review proceedings. In any triennial review in which the Virginia Commission determines that the utility’s earnings are more than 70 basis points above its authorized return on equity, base rates are subject to reduction prospectively and customer refunds would be due unless the total customer credit reinvestment offset elected by the utility equals or exceeds the amount of earnings in excess of the 70 basis points. In the 2021 review, any such rate reduction is limited to $50 million. The legislation also includes provisions requiring Virginia Power to provide current customers one-time after-tax) non-jurisdictional In addition, Virginia Power reduced base rates on an annual basis by $125 million effective July 2018, to reflect the estimated effect of the 2017 Tax Reform Act, which is subject to adjustment effective April 2019. In May and June 2018, Virginia Power submitted filings detailing the implementation plan for interim reductions in rates for generation and distribution services pursuant to the GTSA. In July 2018, Virginia Power filed a petition with the Virginia Commission for approval of the first three years of its ten-year Virginia Fuel Expenses In May 2018, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $1.5 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2018. Virginia Power’s proposed fuel rate represented a fuel revenue increase of $222 million when applied to projected kilowatt-hour sales for the period July 1, 2018 to June 30, 2019. In August 2018, the Virginia Commission approved Virginia Power’s fuel rate with an increase of $209 million. Solar Facility Projects In July 2018, Virginia Power filed an application with the Virginia Commission for CPCNs to construct two solar facilities. Colonial Trail West and Spring Grove 1 are estimated to cost approximately $410 million, excluding financing costs. Colonial Trail West and Spring Grove 1 are expected to commence commercial operations, subject to regulatory approvals associated with the projects, in the fourth quarter of 2019 and the fourth quarter of 2020, respectively. Virginia Power also applied for approval of Rider US-3 20-year US-3 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 2018, Virginia Power proposed a $755 million total revenue requirement consisting of $468 million for the transmission component of Virginia Power’s base rates and $287 million for Rider T1. This total revenue requirement represents a $146 million increase versus the revenues to be produced during the rate year under current rates. In August 2018, the Virginia Commission approved a total revenue requirement of $630 million, including Rider T1, subject to true-up, • The Virginia Commission previously approved Rider U in conjunction with cost recovery to move certain electric distribution facilities underground as authorized by Virginia legislation. In March 2018, Virginia Power requested approval of its third phase of conversions totaling $179 million and a balance of $65 million in second phase conversions not previously approved for recovery through Rider U. Virginia Power also proposed a total $73 million revenue requirement for the rate year beginning February 1, 2019 for continuing recovery of the previously approved first and second phase conversions and the proposed second and third phase conversions. In December 2018, the Virginia Commission approved a total $70 million annual revenue requirement effective February 1, 2019, a total capital investment of $179 million for third phase conversions and a balance of $64 million for second phase conversions not previously approved for recovery through Rider U. • The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In October 2018, Virginia Power requested approval to implement ten new energy efficiency programs and one new demand-response DSM program for five years, subject to future extensions, with a $262 million cost cap, and proposed a total $49 million revenue requirement for the rate year beginning July 1, 2019, which represents an $18 million increase over the previous year. This matter is pending. Additional significant riders associated with various Virginia Power projects are as follows: Rider Name Application Date Approval Date Rate Year Beginning Total Increase Rider S June 2018 February 2019 April 2019 $ 215 $ (3 ) Rider GV June 2018 February 2019 April 2019 120 38 Rider W June 2018 February 2019 April 2019 105 (4 ) Rider R June 2018 February 2019 April 2019 57 (9 ) Rider B June 2018 February 2019 April 2019 38 (9 ) Rider BW October Pending September 2019 123 7 Rider US-2 October Pending September 2019 16 3 Rider E December Pending November 2019 114 N/A Coastal Virginia Offshore Wind Project In November 2018, Virginia Power received approval from the Virginia Commission for its petition seeking a prudency determination as provided in the GTSA with respect to the proposed Coastal Virginia Offshore Wind project consisting of two 6 MW wind turbine generators located approximately 27 miles off the coast of Virginia Beach, Virginia in federal waters, and for a CPCN, for the generation tie line connecting the generators to shore. This project is expected to cost approximately $300 million and to be placed into service by the end of 2020. 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. As of July 2017, Virginia Power has received all major required permits and approvals and is proceeding with construction of the project. In connection with the receipt of the permit from the U.S. Army Corps of Engineers in July 2017, Virginia Power was required to make payments totaling approximately $90 million to fund improvements to historical and cultural resources near the project. Accordingly, in July 2017, Virginia Power recorded an increase to property, plant and equipment and a corresponding liability for these payment obligations. Through December 31, 2017, Virginia Power had made $90 million of such payments. Also in July 2017, the National Parks Conservation Association filed a lawsuit in U.S. District Court for the D.C. Circuit seeking to set aside the permit granted by the U.S. Army Corps of Engineers for the project and requested a preliminary injunction against the permit. In August 2017, the National Trust for Historic Preservation and Preservation Virginia filed a similar lawsuit in U.S. District Court for the D.C. Circuit. In October 2017, the preliminary injunction requests were denied. In May 2018, the District Court granted summary judgment in favor of the U.S. Army Corps of Engineers and Virginia Power and dismissed both lawsuits. In June 2018, the National Parks Conservation Association and the National Trust for Historic Preservation and Preservation Virginia appealed that decision to the U.S. Court of Appeals for the D.C. Circuit. The appeal is pending. Also in June 2018, the National Parks Conservation Association filed requests with the U.S. District Court for the District of Columbia and the U.S. Court of Appeals for the D.C. Circuit for an injunction against the permit pending appeal. The U.S. District Court for the District of Columbia denied the injunction request in June 2018 and the U.S. Court of Appeals for the D.C. Circuit similarly denied the request in July 2018. 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 rights-of-way. In June 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in King and Queen, King William, and New Kent Counties, Virginia four separate segments of 230 kV transmission line between Lanexa and the Northern Neck in Virginia. In February 2019, Virginia Power withdrew two of the segments from the application. As a result, the total estimated cost of the project is approximately $30 million. This matter is pending. Additional significant Virginia Power electric transmission projects approved and applied for in 2018 are as follows: Description and Location of Project Application Date Approval Date Type of Line Miles Lines Cost (millions) Rebuild and operate existing 115 kV transmission lines between the Possum Point Switching Station and Northern Virginia Electric Cooperative’s Smoketown delivery point June 2017 February 2018 230 kV 9 $ 20 Rebuild and operate between the Dooms substation and the Valley substation, along with associated substation work September 2017 September 2018 500 kV 18 65 Build and operate between the Idylwood and Tysons substations, along with associated substation work November 2017 September 2018 230 kV 4 125 Rebuild and operate between the Chesterfield and Hopewell substations, along with associated substation work May 2018 November 2018 230 kV 8 30 Rebuild and operate between the Chesterfield and Lakeside substations, along with associated substation work May 2018 December 2018 230 kV 21 35 Rebuild and operate between the Landstown and Thrasher substations, along with associated substation work June 2018 December 2018 230 kV 8.5 20 Partial rebuild of overhead transmission lines in Alleghany County, Virginia and Covington, Virginia August 2018 Pending 138 kV 5 15 Build a new substation and connect three existing transmission lines thereto in Fluvanna County, Virginia October 2018 Pending 230 kV <1 30 N ORTH AROLINA EGULATION In August 2018, Virginia Power submitted its annual filing to the North Carolina Commission to adjust the fuel component of its electric rates. Virginia Power proposed a total $24 million increase to the fuel component of its electric rates for the rate year beginning February 1, 2019. As a mitigation alternative, Virginia Power proposed recovering 50% in the February 1, 2019 to the January 31, 2020 rate period and the remaining 50% in the following rate period. In January 2019, the North Carolina Commission approved Virginia Power’s full proposed fuel charge adjustment of $24 million. O HIO EGULATION 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 September 2016, the Ohio Commission approved a stipulation filed jointly by East Ohio and the Staff of the Ohio Commission to settle East Ohio’s pending application. As requested, the PIR program and associated cost recovery will continue for another five-year term, calendar years 2017 through 2021, and East Ohio will be permitted to increase its annual capital expenditures to $200 million by 2018 and 3% per year thereafter subject to the cost recovery rate increase caps proposed by East Ohio. In April 2018, the Ohio Commission approved East Ohio’s application to adjust the PIR cost recovery rates for 2017 costs. The filing reflects gross plant investment for 2017 of $204 million, cumulative gross plant investment of $1.4 billion and a revenue requirement of $165 million. 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 April 2018, the Ohio Commission approved East Ohio’s application to adjust its AMR cost recovery rate for 2017 costs. The filing reflects a revenue requirement of approximately $5 million. 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 May 2018, East Ohio filed its annual update of the PIPP rider with the Ohio Commission. In July 2018, East Ohio’s annual update of the PIPP rider was automatically approved by the Ohio Commission after a 45-day 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 September 2018, the Ohio Commission approved East Ohio’s application requesting approval of its UEX Rider to reflect a refund of over-recovered accumulated bad debt expense of approximately $11 million as of March 31, 2018, and recovery of prospective net bad debt expense projected to total $16 million for the twelve-month period from April 2018 to March 2019. DSM Rider East Ohio has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In November 2018, East Ohio filed an application with the Ohio Commission seeking approval of an adjustment to the DSM rider to recover a total of $4 million, which includes an over-recovery of costs during the preceding 12-month W EST IRGINIA EGULATION In May 2018, Hope filed a PREP application with the West Virginia Commission requesting approval to recover PREP costs related to $31 million and $36 million of projected capital investment for 2018 and 2019, respectively. The application also includes a true-up U TAH AND YOMING EGULATION Fuel Deferral In May 2018, Questar Gas submitted filings with both the Utah Commission and the Wyoming Commission for an approximately $86 million gas cost decrease reflecting forecasted decreases in commodity costs. The Utah Commission and the Wyoming Commission both approved the filings in May 2018 with rates effective June 2018. In October 2018, Questar Gas submitted filings with both the Utah Commission and the Wyoming Commission for an approximately $48 million gas cost decrease reflecting forecasted decreases in commodity costs. The Utah Commission and the Wyoming Commission both approved the filings in October 2018 with rates effective November 2018. In October 2018, the Utah Commission denied Questar Gas’ request for pre-approval Infrastructure Replacement Tracker During 2018, Questar Gas filed applications with the Utah Commission to increase its infrastructure replacement surcharge to collect an additional $11 million in revenue in 2019 related to $85 million in 2018 capital investment. The Utah Commission approved the applications in the fourth quarter of 2018. FERC—G AS Cove Point In March 2018, Cove Point submitted its annual electric power cost adjustment to FERC requesting approval to recover $30 million. FERC approved the adjustment in March 2018. In June 2015, Cove Point executed two binding precedent agreements for the approximately $150 million Eastern Market Access Project. In January 2018, Cove Point received FERC authorization to construct and operate the project facilities, which are expected to be placed in service in the second half of 2019. In October 2018, Cove Point announced it is evaluating alternatives to a proposed Charles County, Maryland compressor station that was initially part of this project and in December 2018, after working with project customers for alternative solutions, decided not to pursue further construction at this location resulting in a revised project estimate of approximately $45 million and a write-off pre-tax after-tax) DETI In September 2018, DETI submitted its annual transportation cost rate adjustment to FERC requesting approval to recover $37 million. Also in September 2018, DETI submitted its annual electric power cost adjustment to FERC requesting approval to recover $7 million. In October 2018, FERC approved these adjustments. In August 2018, DETI executed a binding precedent agreement with a customer for the West Loo

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	N OTE SSET ETIREMENT 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 Energy and Virginia Power’s AROs are primarily associated with the decommissioning of their nuclear generation facilities and ash pond and landfill closures. Dominion Energy 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 Energy’s LNG facility, Dominion Energy and Dominion Energy Gas’ storage wells in their 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 Energy 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 2017 and 2018 were as follows: Amount (millions) Dominion Energy AROs at December 31, 2016 $ 2,485 Obligations incurred during the period 37 Obligations settled during the period (214 ) Revisions in estimated cash flows 7 Accretion 117 AROs at December 31, 2017 (1) $ 2,432 Obligations incurred during the period 20 Obligations settled during the period (159 ) Revisions in estimated cash flows (2) 120 Accretion 119 AROs at December 31, 2018 (1) $ 2,532 Virginia Power AROs at December 31, 2016 $ 1,443 Obligations incurred during the period 11 Obligations settled during the period (152 ) Revisions in estimated cash flows (1 ) Accretion 64 AROs at December 31, 2017 $ 1,365 Obligations incurred during the period 14 Obligations settled during the period (119 ) Revisions in estimated cash flows (2) 120 Accretion 65 AROs at December 31, 2018 $ 1,445 Dominion Energy Gas AROs at December 31, 2016 $ 156 Obligations incurred during the period 2 Obligations settled during the period (7 ) Accretion 9 AROs at December 31, 2017 (3) $ 160 Obligations incurred during the period 4 Obligations settled during the period (6 ) Accretion 9 AROs at December 31, 2018 (3) $ 167 (1) Includes $263 million and $282 million reported in other current liabilities at December 31, 2017, and 2018, respectively. (2) Reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information. (3) Includes $146 million and $153 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2017 and 2018, respectively. Dominion Energy and Virginia Power have established trusts dedicated to funding the future decommissioning of their nuclear plants. At December 31, 2018 and 2017, the aggregate fair value of Dominion Energy’s trusts, consisting primarily of equity and debt securities, totaled $4.9 billion and $5.1 billion, respectively. At December 31, 2018 and 2017, the aggregate fair value of Virginia Power’s trusts, consisting primarily of debt and equity securities, totaled $2.4 billion for both periods.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	N OTE ARIABLE NTEREST 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. D OMINION NERGY At December 31, 2018, Dominion Energy owned the general partner, 60.9% of the common and subordinated units and 37.5% of the convertible preferred interests in Dominion Energy Midstream, which owned a preferred equity interest and the general partner interest in Cove Point. In January 2019, Dominion Energy acquired all outstanding partnership interests not owned by Dominion Energy and Dominion Energy Midstream became a wholly-owned subsidiary of Dominion Energy. Dominion Energy previously concluded that Dominion Energy Midstream was a VIE due to the limited partners lacking the characteristics of a controlling financial interest. Dominion Energy was the primary beneficiary of Dominion Energy Midstream and Dominion Energy Midstream was the primary beneficiary of Cove Point as they had the power to direct the activities that most significantly impact their economic performance as well as to absorb losses and benefits which could be significant to them. At December 31, 2018, Dominion Energy owns the manager and 67% of the membership interest in certain merchant solar facilities, as discussed in Note 2. Dominion Energy has concluded that these entities are VIEs due to the members lacking the characteristics of a controlling financial interest. In addition, in 2016 Dominion Energy created a wholly owned subsidiary, SBL Holdco, as a holding company of its interest in the VIE merchant solar facilities and accordingly SBL Holdco is a VIE. Dominion Energy is the primary beneficiary of SBL Holdco and the merchant solar facilities, as it has the power to direct the activities that most significantly impact their economic performance as well as the obligation to absorb losses and benefits which could be significant to them. Dominion Energy’s securities due within one year and long-term debt include $31 million and $299 million, respectively, of debt issued by SBL Holdco net of issuance costs that is nonrecourse to Dominion Energy and is secured by SBL Holdco’s interest in certain merchant solar facilities. Dominion Energy owns a 48% membership interest in Atlantic Coast Pipeline. See Note 9 for more details regarding the nature of this entity. Dominion Energy concluded that Atlantic Coast Pipeline is a VIE because it has insufficient equity to finance its activities without additional subordinated financial support. Dominion Energy 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 Energy is obligated to provide capital contributions based on its ownership percentage. Dominion Energy’s maximum exposure to loss is limited to its current and future investment as well as any obligations under a guarantee provided. See Note 22 for more information. D OMINION NERGY AND IRGINIA OWER Dominion Energy and Virginia Power’s nuclear decommissioning trust funds and Dominion Energy’s rabbi trusts hold investments in limited partnerships or similar type entities (see Note 9 for further details). Dominion Energy and Virginia Power concluded that these partnership investments are VIEs due to the limited partners lacking the characteristics of a controlling financial interest. Dominion Energy and Virginia Power have concluded neither is the primary beneficiary as they do not have the power to direct the activities that most significantly impact these VIEs’ economic performance. Dominion Energy and Virginia Power are obligated to provide capital contributions to the partnerships as required by each partnership agreement based on their ownership percentages. Dominion Energy and Virginia Power’s maximum exposure to loss is limited to their current and future investments. D OMINION NERGY AND OMINION NERGY AS Dominion Energy previously concluded that Iroquois was a VIE because a non-affiliated V IRGINIA OWER Virginia Power had long-term power and capacity contracts with three non-utility non-utility non-utility non-utility D OMINION NERGY AS DETI 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 DETI holds a membership interest in Atlantic Coast Pipeline, therefore DETI 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. DETI 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. DETI has no obligation to absorb any losses of the VIE. See Note 24 for information about associated related party receivable balances. V IRGINIA OWER AND OMINION NERGY AS Virginia Power and Dominion Energy Gas purchased shared services from DES, an affiliated VIE, of $335 million and $126 million, $340 million and $126 million, and $346 million and $123 million for the years ended December 31, 2018, 2017 and 2016, respectively. Virginia Power and Dominion Energy Gas’ Consolidated Balance Sheets included amounts due to DES of $107 million and $46 million, respectively, at December 31, 2018, and $36 million and $14 million, respectively, at December 31, 2017, recorded in payables to affiliates in the Consolidated Balance Sheets. Virginia Power and Dominion Energy Gas determined that neither is the primary beneficiary of DES as neither has both the power to direct the activities that most significantly impact its economic performance as well as the obligation to absorb losses and benefits which could be significant to it. DES provides accounting, legal, finance and certain administrative and technical services to all Dominion Energy subsidiaries, including Virginia Power and Dominion Energy Gas. Virginia Power and Dominion Energy Gas have no obligation to absorb more than their allocated shares of DES costs.

Short-Term Debt And Credit Agre

Short-Term Debt And Credit Agreements	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Short-Term Debt And Credit Agreements	N OTE HORT TERM EBT AND REDIT 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 addition, Dominion Energy utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by commodity prices, hedging levels, Dominion Energy’s credit ratings and the credit quality of its counterparties. D OMINION NERGY In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities were as follows: Facility Outstanding (1) Outstanding Facility (millions) At December 31, 2018 Joint revolving credit facility (2) $ 6,000 $ 324 $88 $ 5,588 At December 31, 2017 Joint revolving credit facility (3) $ 5,000 $3,298 $— $ 1,702 Joint revolving credit facility (3) 500 — 76 424 Total $ 5,500 $3,298 $76 $ 2,126 (1) The weighted-average interest rates of the outstanding commercial paper supported by Dominion Energy’s credit facilities were 2.93% and 1.61% at December 31, 2018 and 2017, respectively. (2) This credit facility matures in March 2023 and can be used by the Companies 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. (3) These credit facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The facilities were scheduled to mature in April 2020 and were 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. In connection with the SCANA Combination, Dominion Energy intends to terminate SCANA, SCE&G and PSNC’s existing credit facilities, and add SCE&G as a co-borrower co-borrowers, Questar Gas’ short-term financing is supported through its access as co-borrower sub-limit In addition to the credit facilities mentioned above, SBL Holdco has $30 million of credit facilities which had an original stated maturity date of December 2017 with automatic one-year one-year In February and June 2018, Dominion Energy borrowed $950 million and $500 million, respectively, under 364-Day In March 2018, Dominion Energy Midstream entered into a $500 million revolving credit facility. The credit facility was scheduled to mature in March 2021, bore interest at a variable rate, and was used to support bank borrowings and the issuance of commercial paper, as well as to support up to $250 million of letters of credit. At December 31, 2018, Dominion Energy Midstream had $73 million outstanding under this credit facility. In February 2019, Dominion Energy Midstream terminated the facility subsequent to repaying the outstanding balance, plus accrued interest. In October 2018, Dominion Energy entered into a credit agreement, which allows Dominion Energy to issue up to approximately $21 million in letters of credit. The facility terminates in June 2020. At December 31, 2018, Dominion Energy had $21 million in letters of credit outstanding under this agreement. V IRGINIA OWER In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. Virginia Power’s short-term financing is supported through its access as co-borrower Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion Energy, Dominion Energy Gas and Questar Gas were as follows: Facility Outstanding (1) Outstanding (millions) At December 31, 2018 Joint revolving credit facility (2) $6,000 $314 $16 At December 31, 2017 Joint revolving credit facility (3) $5,000 $542 $— Joint revolving credit facility (3) 500 — — Total $5,500 $542 $— (1) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.94% and 1.65% at December 31, 2018 and 2017, respectively. (2) The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers sub-limit sub-limit sub-limit, sub-limit sub-limit, (3) These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The full amount of the facilities was available to Virginia Power, less any amounts outstanding to co-borrowers sub-limit, In addition to the credit facility commitments mentioned above, Virginia Power also had a $100 million credit facility with a maturity date of April 2020. In March 2018, Virginia Power redeemed its variable rate tax-exempt D OMINION NERGY AS In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. Dominion Energy Gas’ short-term financing is supported by its access as co-borrower Dominion Energy Gas’ share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion Energy, Virginia Power and Questar Gas were as follows: Facility Outstanding (1) Outstanding (millions) At December 31, 2018 Joint revolving credit facility (2) $1,500 $ 10 $— At December 31, 2017 Joint revolving credit facility (3) $1,000 $629 $— Joint revolving credit facility (3) 500 — — Total $1,500 $629 $— (1) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.58% and 1.57% at December 31, 2018 and 2017, respectively. (2) A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers sub-limit sub-limit sub-limit, sub-limit sub-limit, (3) These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. A maximum of a combined $1.5 billion of the facilities was available to Dominion Energy Gas, assuming adequate capacity was available after giving effect to uses by co-borrowers sub-limit,

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-Term Debt	N OTE ONG TERM EBT At December 31, 2018 Weighted- average Coupon (1) 2018 2017 (millions, except percentages) Dominion Energy Gas Holdings, LLC: Unsecured Senior Notes: Variable rate, due 2021 3.39 % $ 500 $ — 2.5% to 3.55%, due 2019 to 2023 2.90 % 1,800 1,800 3.317% to 4.8%, due 2024 to 2044 (2) 4.12 % 1,787 1,800 Dominion Energy Gas Holdings, LLC total principal $ 4,087 $ 3,600 Securities due within one year 2.50 % (449 ) — Unamortized discount and debt issuance costs (29 ) (30 ) Dominion Energy Gas Holdings, LLC total long-term debt $ 3,609 $ 3,570 Virginia Electric and Power Company: Unsecured Senior Notes: 1.2% to 5.4%, due 2018 to 2023 3.35 % $ 1,800 $ 2,650 2.95% to 8.875%, due 2024 to 2048 4.61 % 9,290 7,990 Tax-Exempt (3) Variable rates, due 2024 to 2027 — 100 1.75% to 5.6%, due 2023 to 2041 2.18 % 664 678 Virginia Electric and Power Company total principal $ 11,754 $ 11,418 Securities due within one year 5.00 % (350 ) (850 ) Unamortized discount, premium and debt issuances costs, net (83 ) (72 ) Virginia Electric and Power Company total long-term debt $ 11,321 $ 10,496 Dominion Energy, Inc.: Unsecured Senior Notes (4) Variable rates, due 2019 and 2020 3.23 % $ 800 $ 800 1.5% to 6.4%, due 2018 to 2022 2.75 % 2,550 5,800 2.85% to 7.0%, due 2024 to 2044 4.81 % 4,849 5,049 Unsecured Junior Subordinated Notes: 2.579% to 4.104%, due 2019 to 2021 3.08 % 2,100 2,100 Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.25% and 5.75%, due 2054 and 2076 5.48 % 1,485 1,485 Variable rates, due 2066 5.26 % 422 422 Remarketable Subordinated Notes, 2.0%, due 2021 and 2024 2.00 % 1,400 1,400 Unsecured Debentures and Senior Notes (5) 6.8% and 6.875%, due 2026 and 2027 6.81 % 89 89 Unsecured Senior and Medium-Term Notes (6) 5.31% and 6.3%, due 2018 — 120 2.98% to 7.20%, due 2024 to 2051 4.25 % 750 600 Secured Senior Notes, 4.82%, due 2042 (7) 4.82 % 362 — Term Loans, variable rates, due 2023 and 2024 (8) 4.85 % 582 638 Tax-Exempt (9) 1.55 % 27 27 Capital leases, 4.14% to 6.04%, due 2019 to 2029 5.99 % 39 — Dominion Energy Midstream Partners, LP: Term Loans, variable rates, due 2019 and 2021 (10)(11) 4.13 % 3,300 300 Revolving Credit Agreement, variable rates, due 2021 (11) 3.55 % 73 — Unsecured Senior and Medium-Term Notes, 5.83% and 6.48%, due 2018 (12) — 255 Unsecured Senior Notes, 3.53% to 4.875%, due 2028 to 2041 (12) 4.23 % 430 180 Dominion Energy Gas Holdings, LLC total principal (from above) 4,087 3,600 Virginia Electric and Power Company total principal (from above) 11,754 11,418 Dominion Energy, Inc. total principal $ 35,109 $ 34,293 Fair value hedge valuation (13) (20 ) (22 ) Securities due within one year (14)(15) 3.23 % (3,624 ) (3,078 ) Credit facility borrowings (11) 3.55 % (73 ) — Unamortized discount, premium and debt issuance costs, net (248 ) (245 ) Dominion Energy, Inc. total long-term debt $ 31,144 $ 30,948 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2018. (2) Amount includes foreign currency remeasurement adjustments. (3) These financings relate to certain pollution control equipment at Virginia Power’s generating facilities. In March 2018, Virginia Power redeemed certain variable rate tax-exempt (4) In November and December 2018, Dominion Energy redeemed certain senior notes prior to their stated maturity. See below for a discussion of the senior note redemptions. (5) Represents debt assumed by Dominion Energy from the merger of its former CNG subsidiary. (6) Represents debt obligations of Questar Gas. See Note 3 for more information. (7) Represents debt obligations of Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain merchant solar facilities. (8) Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt is nonrecourse to Dominion Energy and is secured by SBL Holdco and Dominion Solar Projects III, Inc.’s interest in certain merchant solar facilities. (9) Represents debt obligations of a DGI subsidiary. (10) Includes debt obligations of Cove Point that are secured by Dominion Energy’s common equity interest in Cove Point. (11) In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy’s Consolidated Balance Sheets at December 31, 2018. (12) Represents debt obligations of Dominion Energy Questar Pipeline. See Note 3 for more information. (13) Represents the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt. (14) 2017 excludes $250 million of Dominion Energy Questar Pipeline’s senior notes that matured in February 2018 using proceeds from the January 2018 issuance, through private placements, of $100 million and $150 million of senior notes that mature in 2028 and 2038, respectively. (15) Includes $20 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc. 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, 2018, were as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions, except percentages) Dominion Energy Gas $ 450 $ 700 $ 500 $ — $ 650 $ 1,787 $ 4,087 Weighted-average Coupon 2.50 % 2.80 % 3.39 % 3.29 % 4.12 % Virginia Power Unsecured Senior Notes $ 350 $ — $ — $ 750 $ 700 $ 9,290 $ 11,090 Tax-Exempt — — — — 40 624 664 Total $ 350 $ — $ — $ 750 $ 740 $ 9,914 $ 11,754 Weighted-average Coupon 5.00 % 3.15 % 2.87 % 4.45 % Dominion Energy Term Loans (1)(2) $ 336 $ 35 $ 3,035 $ 34 $ 273 $ 169 $ 3,882 Credit Facility Borrowings (2) — — 73 — — — 73 Unsecured Senior Notes 2,700 1,000 900 1,500 1,350 17,195 24,645 Secured Senior Notes 17 15 17 19 16 278 362 Tax-Exempt — — — — 40 651 691 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Unsecured Junior Subordinated Notes 550 1,000 550 — — — 2,100 Enhanced Junior Subordinated Notes — — — — — 1,907 1,907 Remarketable Subordinated Notes — — 700 — — 700 1,400 Capital leases 4 4 4 3 3 21 39 Total $ 3,607 $ 2,054 $ 5,279 $ 1,556 $ 1,682 $ 20,931 $ 35,109 Weighted-average Coupon 3.23 % 2.80 % 3.64 % 3.02 % 3.41 % 4.51 % (1) Excludes mandatory prepayments associated with SBL Holdco and Dominion Solar Projects III, Inc. based on cash flows in excess of debt service. At December 31, 2018, $20 million of estimated mandatory prepayments due within one year were included in securities due within one year in Dominion Energy’s Consolidated Balance Sheets. (2) In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy’s Consolidated Balance Sheets at December 31, 2018. The Companies’ short-term credit facility and long-term debt agreements contain customary covenants and default provisions. As of December 31, 2018, there were no events of default under these covenants. Senior Note Redemptions In November 2018 and December 2018, Dominion Energy redeemed the following outstanding series of senior notes: 2011 Series A 4.45% Senior Notes due 2021, 2014 Series B 2.50% Senior Notes due 2019, 2014 Series C 3.625% Senior Notes due 2024 and 2018 Series A Floating Rate Senior Notes due 2020 with an aggregate outstanding principal of $2.2 billion. The aggregate redemption price paid was $2.2 billion and represents the principal amount outstanding, accrued and unpaid interest and the applicable make-whole premium of $34 million. Total charges of $69 million, including the make-whole premium, were recognized and recorded in interest expense in Dominion Energy’s Consolidated Statements of Income. Enhanced Junior Subordinated Notes In June 2006 and September 2006, Dominion Energy issued $300 million of June 2006 hybrids and $500 million of September 2006 hybrids, respectively. The June 2006 hybrids bear interest at three-month LIBOR plus 2.825%, reset quarterly. Previously, interest was fixed at 7.5% per year. The September 2006 hybrids bear interest at the three-month LIBOR plus 2.3%, reset quarterly. In October 2014, Dominion Energy 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 Energy 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 Energy 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 Energy 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 Energy executed RCCs in connection with its issuance of the June 2006 hybrids and the September 2006 hybrids. Under the terms of the RCCs, Dominion Energy covenants to and for the benefit of designated covered debtholders, as may be designated from time to time, that Dominion Energy 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 Energy 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 Energy 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. The proceeds Dominion Energy receives from the replacement offering, adjusted by a predetermined factor, must equal or exceed the redemption or repurchase price. In the first quarter of 2016, Dominion Energy purchased and cancelled $38 million and $4 million of the June 2006 hybrids and the September 2006 hybrids, respectively. In July 2016, Dominion Energy launched a tender offer to purchase up to $200 million in aggregate of additional June 2006 hybrids and September 2006 hybrids, which expired on August 1, 2016. In connection with the tender offer, Dominion Energy purchased and cancelled $125 million and $74 million of the June 2006 hybrids and the September 2006 hybrids, respectively. All purchases were conducted in compliance with the applicable RCC. Also in July 2016, Dominion Energy issued $800 million of 5.25% July 2016 hybrids. The proceeds were used for general corporate purposes, including to finance the tender offer. The July 2016 hybrids are listed on the NYSE under the symbol DRUA. Remarketable Subordinated Notes In June 2013, Dominion Energy issued $550 million of 2013 Series A 6.125% Equity Units and $550 million of 2013 Series B 6.0% Equity Units, initially in the form of Corporate Units. In July 2014, Dominion Energy issued $1.0 billion of 2014 Series A 6.375% Equity Units, initially in the form of Corporate Units. The Corporate Units were listed on the NYSE under the symbols DCUA, DCUB and DCUC respectively. Each Corporate Unit consisted of a stock purchase contract and 1/20 interest in a RSN issued by Dominion Energy. The stock purchase contracts obligated the holders to purchase shares of Dominion Energy common stock at a future settlement date prior to the relevant RSN maturity date. The purchase price paid under the stock purchase contracts was $50 per Corporate Unit and the number of shares purchased was determined under a formula based upon the average closing price of Dominion Energy common stock near the settlement date. The RSNs were pledged as collateral to secure the purchase of common stock under the related stock purchase contracts. In May 2017, Dominion Energy successfully remarketed the $1.0 billion 2014 Series A 1.50% RSNs due 2020 pursuant to the terms of the related 2014 Equity Units. In connection with the remarketing, the interest rate on the junior subordinated notes was reset to 2.579%, payable on a semi-annual basis and Dominion Energy ceased to have the ability to redeem the notes at its option or defer interest payments. In March 2016 and May 2016, Dominion Energy successfully remarketed the $550 million 2013 Series A 1.07% RSNs due 2021 and the $550 million 2013 Series B 1.18% RSNs due 2019, respectively, pursuant to the terms of the related 2013 Equity Units. In connection with the remarketings, the interest rate on the Series A and Series B junior subordinated notes was reset to 4.104% and 2.962%, respectively, payable on a semi-annual basis and Dominion Energy ceased to have the ability to redeem the notes at its option or defer interest payments. At December 31, 2018, the securities are included in junior subordinated notes in Dominion Energy’s Consolidated Balance Sheets. Dominion Energy did not receive any proceeds from the remarketings. Remarketing proceeds belonged to the investors holding the related equity units and were temporarily used to purchase a portfolio of treasury securities. Upon maturity of each portfolio, the proceeds were applied on behalf of investors on the related stock purchase contract settlement date to pay the purchase price to Dominion Energy for issuance of 12.5 million shares of its common stock in July 2017 and 8.5 million shares of its common stock in both April 2016 and July 2016. See Issuance of Common Stock below for a description of common stock issued by Dominion Energy under the stock purchase contracts. In August 2016, Dominion Energy issued $1.4 billion of 2016 Series A 6.75% Equity Units, initially in the form of Corporate Units. The Corporate Units are listed on the NYSE under the symbol DCUD. The net proceeds from the 2016 Equity Units were used to finance the Dominion Energy Questar Combination. See Note 3 for more information. Each 2016 Series A Corporate Unit consists of a stock purchase contract, a 1/40 interest in a 2016 Series A-1 A-2 Dominion Energy makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion Energy 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 Energy 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 Energy 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 Energy 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 Energy applies the treasury stock method to the equity units. Pursuant to the terms of the 2016 Equity Units, Dominion Energy expects to remarket both the 2016 Series A-1 A-2 Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Dominion Energy will issue between 15.1 million and 18.9 million shares in August 2019. A total of 23.1 million shares of Dominion Energy’s common stock has been reserved for issuance in connection with the stock purchase contracts. Selected information about Dominion Energy’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 (millions, except interest rates) 8/15/2016 (2) 28 $ 1,374.8 $1,400.0 2.000 % (3) 4.750 % $190.6 8/15/2019 (1) Payments of $64 million and $101 million were made in 2018 and 2017, respectively, including payments for the remarketed 2014 Series A notes. The stock purchase contract liability was $47 million and $111 million at December 31, 2018 and 2017, respectively. (2) The maturity dates of the $700 million Series A-1 A-2 (3) Annual interest rate applies to each of the Series A-1 A-2

Preferred Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Preferred Stock	N OTE REFERRED TOCK Dominion Energy is authorized to issue up to 20 million shares of preferred stock; however, none were issued and outstanding at December 31, 2018 or 2017. Virginia Power is authorized to issue up to 10 million shares of preferred stock, $100 liquidation preference; however, none were issued and outstanding at December 31, 2018 or 2017.

Equity

Equity	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity	N OTE QUITY Issuance of Common Stock D OMINION NERGY Dominion Energy maintains Dominion Energy Direct ® During 2018, Dominion Energy received cash proceeds, net of fees and commissions, of $2.5 billion from the issuance of approximately 36 million shares of common stock through various programs including the forward sale agreements described below resulting in approximately 681 million shares of common stock outstanding at December 31, 2018. These proceeds include cash of $315 million received from the issuance of 4.5 million of such shares through Dominion Energy Direct ® In July 2017, Dominion Energy issued 12.5 million shares under the related stock purchase contracts entered into as part of Dominion Energy’s 2014 Equity Units and received proceeds of $1.0 billion. In both April 2016 and July 2016, Dominion Energy issued 8.5 million shares under the related stock purchase contracts entered into as part of Dominion Energy’s 2013 Equity Units and received $1.1 billion of total proceeds. Additionally, Dominion Energy completed a market issuance of equity in April 2016 of 10.2 million shares and received proceeds of $756 million through a registered underwritten public offering. A portion of the net proceeds was used to finance the Dominion Energy Questar Combination. See Note 3 for more information. In June 2017, Dominion Energy 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 at-the-market at-the-market at-the-market Dominion Energy entered in March 2018, and closed in April 2018, separate forward sale agreements with Goldman Sachs & Co. LLC and Credit Suisse Capital LLC, as forward purchasers, and an underwriting agreement with Credit Suisse Securities (USA) LLC and Goldman Sachs & Co. LLC, as representatives of the several underwriters named therein, relating to an aggregate of 20 million shares of Dominion Energy common stock. The underwriting agreement granted the underwriters a 30-day See Note 3 to the Consolidated Financial Statements for information on the issuance of Dominion Energy common stock in January 2019 in connection with the SCANA Combination. Also in January 2019, Dominion Energy acquired all outstanding partnership interests of Dominion Energy Midstream not owned by Dominion Energy through the issuance of common stock as noted below. V IRGINIA OWER In 2018, 2017 and 2016, Virginia Power did not issue any shares of its common stock to Dominion Energy. Shares Reserved for Issuance Dominion Energy has approximately 76 million shares reserved and available for issuance for Dominion Energy Direct ® Repurchase of Common Stock Dominion Energy did not repurchase any shares in 2018 or 2017 and does not plan to repurchase shares during 2019, 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 Energy Midstream Units In September 2015, Dominion Energy initiated a program to purchase from the market up to $50 million of common units representing limited partner interests in Dominion Energy Midstream, which expired in September 2016. Dominion Energy purchased approximately 658,000 common units for $17 million for the year ended December 31, 2016. In January 2019, Dominion Energy acquired all outstanding partnership interests of Dominion Energy Midstream not owned by Dominion Energy through the issuance of 22.5 million shares of common stock valued at $1.6 billion. The merger was accounted for by Dominion Energy following the guidance for a change in a parent company’s ownership interest in a consolidated subsidiary. Because Dominion Energy controls Dominion Energy Midstream both before and after the merger, the changes in Dominion Energy’s ownership interest in Dominion Energy Midstream were accounted for as an equity transaction and no gain or loss will be recognized. The tax effect of the merger will be presented in common stock. Issuance of Dominion Energy Midstream Units In 2017, Dominion Energy Midstream received $18 million of proceeds from the issuance of common units through its at-the-market In 2016, Dominion Energy Midstream received $482 million of proceeds from the issuance of common units and $490 million of proceeds from the issuance of convertible preferred units. The net proceeds were primarily used to finance a portion of the acquisition of Dominion Energy Questar Pipeline from Dominion Energy. See Note 3 for more information. The holders of the convertible preferred units were entitled to receive cumulative quarterly distributions payable in cash or additional convertible preferred units, subject to certain conditions. The units were convertible into Dominion Energy Midstream common units on a one-for-one In May 2018, all of the subordinated units of Dominion Energy Midstream held by Dominion Energy were converted into common units on a 1:1 ratio following the payment of Dominion Energy Midstream’s distribution for the first quarter of 2018. In June 2018, Dominion Energy, as general partner, exercised an incentive distribution right reset as defined in Dominion Energy Midstream’s partnership agreement and received 26.7 million common units representing limited partner interests in Dominion Energy Midstream. As a result of the increase in its ownership interest in Dominion Energy Midstream, Dominion Energy recorded a decrease in noncontrolling interest, and a correspond-ing increase in shareholders’ equity, of $375 million reflecting the change in the carrying value of the interest in the net assets of Dominion Energy Midstream held by others. Accumulated Other Comprehensive Income (Loss) Presented in the table below is a summary of AOCI by component: At December 31, 2018 2017 (millions) Dominion Energy Net deferred losses on derivatives-hedging activities, net of $79 and $188 tax $ (234 ) $ (301 ) Net unrealized gains on nuclear decommissioning trust funds, net of $— and $(419) tax 2 747 Net unrecognized pension and other postretirement benefit costs, net of $519 and $692 tax (1,465 ) (1,101 ) Other comprehensive loss from equity method investees, net of $— and $2 tax (2 ) (3 ) Total AOCI, including noncontrolling interest $ (1,699 ) $ (658 ) Less other comprehensive income attributable to noncontrolling interest 1 1 Total AOCI, excluding noncontrolling interest $ (1,700 ) $ (659 ) Virginia Power Net deferred losses on derivatives-hedging activities, net of $4 and $8 tax $ (13 ) $ (12 ) Net unrealized gains on nuclear decommissioning trust funds, net of $— and $(47) tax 1 74 Total AOCI $ (12 ) $ 62 Dominion Energy Gas Net deferred losses on derivatives-hedging activities, net of $8 and $15 tax $ (25 ) $ (23 ) Net unrecognized pension costs, net of $56 and $59 tax (144 ) (75 ) Total AOCI $ (169 ) $ (98 ) D OMINION NERGY The following table presents Dominion Energy’s changes in AOCI by component, net of tax: Deferred Unrealized Unrecognized Other Total (millions) Year Ended December 31, 2018 Beginning balance $(302 ) $ 747 $(1,101 ) $(3 ) $(659 ) Other comprehensive income before reclassifications: gains (losses) 30 (18 ) (215 ) 1 (202 ) Amounts reclassified from AOCI: (gains) losses (1) 102 5 78 — 185 Net current period other comprehensive income (loss) 132 (13) (137 ) 1 (17 ) Cumulative-effect of changes in accounting principle (64 ) (732) (227 ) — (1,023 ) Less other comprehensive income (loss) attributable to noncontrolling interest 1 — — — 1 Ending balance $(235 ) $2 $(1,465 ) $(2 ) $(1,700 ) Year Ended December 31, 2017 Beginning balance $(280 ) $ 569 $(1,082 ) $(6 ) $ (799 ) Other comprehensive income before reclassifications: gains (losses) 8 215 (69 ) 3 157 Amounts reclassified from AOCI: (gains) losses (1) (29 ) (37 ) 50 — (16 ) Net current period other comprehensive income (loss) (21 ) 178 (19 ) 3 141 Less other comprehensive income (loss) attributable to noncontrolling interest 1 — — — 1 Ending balance $(302 ) $ 747 $(1,101 ) $(3 ) $ (659 ) (1) See table below for details about these reclassifications. The following table presents Dominion Energy’s reclassifications out of AOCI by component: Details about AOCI components Amounts Affected line item in the (millions) Year Ended December 31, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $90 Operating revenue (14 ) Electric fuel and other Interest rate contracts 48 Interest and related charges Foreign currency contracts 13 Other Income Total 137 Tax (35 ) Income tax expense Total, net of tax $102 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $7 Other income Total 7 Tax (2 ) Income tax expense Total, net of tax $5 Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $(21 ) Other income Amortization of actuarial losses 120 Other income Total 99 Tax (21 ) Income tax expense Total, net of tax $78 Year Ended December 31, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $(81 ) Operating revenue 2 Purchased gas Interest rate contracts 52 Interest and related charges Foreign currency contracts (20 ) Other Income Total (47 ) Tax 18 Income tax expense Total, net of tax $(29 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $(81 ) Other income Impairment 23 Other income Total (58 ) Tax 21 Income tax expense Total, net of tax $(37 ) Unrecognized pension and other postretirement benefit costs: Prior-service costs (credits) $(21 ) Other income Actuarial losses 103 Other income Total 82 Tax (32 ) Income tax expense Total, net of tax $50 V IRGINIA OWER The following table presents Virginia Power’s changes in AOCI by component, net of tax: Deferred Unrealized Total (millions) Year Ended December 31, 2018 Beginning balance $ (12) $ 74 $ 62 Other comprehensive income before reclassifications: gains (losses) 1 — 1 Amounts reclassified from AOCI: (gains) losses (1) 1 — 1 Net current period other comprehensive income (loss) 2 — 2 Cumulative-effect of changes in accounting principle (3 ) (73 ) (76 ) Ending balance $ (13 ) $ 1 $(12 ) Year Ended December 31, 2017 Beginning balance $ (8 ) $ 54 $ 46 Other comprehensive income before reclassifications: gains (losses) (5 ) 24 19 Amounts reclassified from AOCI: gains (losses) (1) 1 (4 ) (3 ) Net current period other comprehensive income (loss) (4 ) 20 16 Ending balance $ (12 ) $ 74 $ 62 (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 Affected line item in the (millions) Year Ended December 31, 2018 (Gains) losses on cash flow hedges: Interest rate contracts $ 1 Interest and related charges Total 1 Tax — Income tax expense Total, net of tax $ 1 Year Ended December 31, 2017 (Gains) losses on cash flow hedges: Interest rate contracts $ 1 Interest and related charges 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 $(9 ) Other income Impairment 2 Other income Total (7 ) Tax 3 Income tax expense Total, net of tax $(4 ) D OMINION NERGY AS The following table presents Dominion Energy Gas’ changes in AOCI by component, net of tax: Deferred gains Unrecognized Total (millions) Year Ended December 31, 2018 Beginning balance $(23 ) $ (75 ) $ (98 ) Other comprehensive income before reclassifications: gains (losses) (17 ) (52 ) (69 ) Amounts reclassified from AOCI: (gains) losses (1) 20 4 24 Net current period other comprehensive income (loss) 3 (48 ) (45 ) Cumulative-effect of changes in accounting principle (5 ) (21 ) (26 ) Ending balance $(25 ) $(144 ) $ (169 ) Year Ended December 31, 2017 Beginning balance $(24 ) $ (99 ) $ (123 ) Other comprehensive income before reclassifications: gains (losses) 5 20 25 Amounts reclassified from AOCI: gains (losses) (1) (4 ) 4 — Net current period other comprehensive income (loss) 1 24 25 Ending balance $(23 ) $ (75 ) $ (98 ) (1) See table below for details about these reclassifications. The following table presents Dominion Energy Gas’ reclassifications out of AOCI by component: Details about AOCI components Amounts Affected line item in the (millions) Year Ended December 31, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 8 Operating revenue Interest rate contracts 6 Interest and related charges Foreign currency contracts 13 Other income Total 27 Tax (7 ) Income tax expense Total, net of tax $ 20 Unrecognized pension costs: Actuarial losses $ 6 Other income Total 6 Tax (2 ) Income tax expense Total, net of tax $ 4 Year Ended December 31, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 8 Operating revenue Interest rate contracts 5 Interest and related charges Foreign currency contracts (20 ) Other income Total (7 ) Tax 3 Income tax expense Total, net of tax $ (4 ) Unrecognized pension costs: Actuarial losses $ 6 Other income Total 6 Tax (2 ) Income tax expense Total, net of tax $ 4 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 non-employee Goal-based stock awards are granted in lieu of cash-based performance grants to certain officers who have not achieved a certain targeted level of share ownership. As of December 31, 2018, unrecognized compensation cost related to nonvested goal-based stock awards was immaterial. Dominion Energy 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 Energy’s results for the years ended December 31, 2018, 2017 and 2016 include $48 million, $45 million, and $33 million, respectively, of compensation costs and $12 million, $16 million, and $11 million, respectively of income tax benefits related to Dominion Energy’s stock-based compensation arrangements. Stock-based compensation cost is reported in other operations and maintenance expense in Dominion Energy’s Consolidated Statements of Income. Excess Tax Benefits are classified as a financing cash flow. R ESTRICTED TOCK Restricted stock grants are made to officers under Dominion Energy’s LTIP and may also be granted to certain key non-officer Shares Weighted —average (thousands) Nonvested at December 31, 2015 855 $66.16 Granted 372 71.67 Vested (301 ) 56.83 Cancelled and forfeited (40 ) 71.75 Nonvested at December 31, 2016 886 $71.40 Granted 454 74.24 Vested (287 ) 68.90 Cancelled and forfeited (10 ) 72.37 Nonvested at December 31, 2017 1,043 $73.32 Granted 534 72.92 Vested (316 ) 73.59 Cancelled and forfeited (53 ) 74.25 Nonvested at December 31, 2018 1,208 $73.03 As of December 31, 2018, unrecognized compensation cost related to nonvested restricted stock awards totaled $49 million and is expected to be recognized over a weighted-average period of 2.1 years. The fair value of restricted stock awards that vested was $23 million, $21 million, and $21 million in 2018, 2017 and 2016, 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 Energy stock and the applicable federal, state and local tax withholding rates. C ASH ASED ERFORMANCE RANTS Cash-based performance grants are made to Dominion Energy’s officers under Dominion Energy’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 2016, a cash-based performance grant was made to officers. Payout of the performance grant occurred in January 2018 based on the achievement of two performance metrics during 2016 and 2017: 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 of the payout under the grant was $12 million. In February 2017, two cash-based performance grants were made to officers as Dominion Energy transitioned from a two-year two-year two-year In February 2018, a cash-based performance grant was made to officers. Payout of the three-year cash-based performance grant is expected to occur by March 15, 2021 based on the achievement of two performance metrics during 2018, 2019 and 2020: TSR relative to that of companies that are members of Dominion Energy’s compensation peer group and ROIC. There are additional opportunities to earn a portion of the awards based on Dominion Energy’s absolute TSR or relative price-earnings ratio performance. At December 31, 2018, the targeted amount of the three-year grant was $16 million and a liability of $5 million had been accrued for this award.

Dividend Restrictions

Dividend Restrictions	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Dividend Restrictions	N OTE IVIDEND 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, 2018, the Virginia Commission had not restricted the payment of dividends by Virginia Power. The North Carolina Commission, in its order approving the SCANA Combination, limited cumulative dividends payable to Dominion Energy by Virginia Power and PSNC to (i) the amount of retained earnings at closing of the SCANA Combination plus (ii) any future earnings recorded by Virginia Power and PSNC after such date. In addition, notice to the North Carolina Commission is required if payment of dividends causes the equity component of Virginia Power and PSNC’s capital structure to fall below 45%. 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, 2018, the Ohio Commission had not restricted the payment of dividends by East Ohio. Pursuant to the SCANA Merger Approval Order, the amount of any SCE&G dividends paid must be reasonable and consistent with the long-term payout ratio of the electric utility industry and gas distribution industry. There is no specific restriction on the payment of dividends by SCE&G. The Utah Commission may prohibit any public service company, including Questar Gas, from declaring or paying a dividend to an affiliate if found to be detrimental to the public interest. At December 31, 2018, the Utah Commission had not restricted the payment of dividends by Questar Gas. Certain agreements associated with the Companies’ credit facility contains 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, 2018. In connection with the SCANA Combination, under the terms of the merger agreement, Dominion Energy could not declare, set aside or pay any dividends on, or make any other distributions (whether in cash, stock or property) in respect of, any of its capital stock, other than regular quarterly cash dividends from January 2018 through January 2019. As part of the merger agreement with Dominion Energy Midstream from November 2018 through January 2019, Dominion Energy could not declare, set aside or pay any dividends on, or make any other distributions (whether in cash, stock or property) in respect of, any of its capital stock, other than regular quarterly cash dividends. See Note 17 for a description of potential restrictions on dividend payments by Dominion Energy in connection with the deferral of interest payments on certain junior subordinated notes and equity units, initially in the form of corporate units.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2018
Retirement Benefits [Abstract]
Employee Benefit Plans	N OTE MPLOYEE ENEFIT LANS Dominion Energy and Dominion Energy Gas—Defined Benefit Plans Dominion Energy provides certain retirement benefits to eligible active employees, retirees and qualifying dependents. Dominion Energy Gas participates in a number of the Dominion Energy-sponsored retirement plans. Under the terms of its benefit plans, Dominion Energy 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 Energy 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 Energy’s funding policy is to contribute annually an amount that is in accordance with the provisions of ERISA. The pension programs also provide benefits to certain retired executives under company-sponsored nonqualified employee benefit plans. The nonqualified plans are funded through contributions to grantor trusts. Dominion Energy 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 Energy Gas employees not represented by collective bargaining units are covered by the Dominion Energy Pension Plan, a defined benefit pension plan sponsored by Dominion Energy that provides benefits to multiple Dominion Energy subsidiaries. Pension benefits for Dominion Energy Gas employees represented by collective bargaining units are covered by separate pension plans for East Ohio and, for DETI, a plan that provides benefits to employees of both DETI and Hope. Employee compensation is the basis for allocating pension costs and obligations between DETI and Hope and determining East Ohio’s share of total pension costs. Retiree healthcare and life insurance benefits for Dominion Energy Gas employees not represented by collective bargaining units are covered by the Dominion Energy Retiree Health and Welfare Plan, a plan sponsored by Dominion Energy that provides certain retiree healthcare and life insurance benefits to multiple Dominion Energy subsidiaries. Retiree healthcare and life insurance benefits for Dominion Energy Gas employees represented by collective bargaining units are covered by separate other postretirement benefit plans for East Ohio and, for DETI, a plan that provides benefits to both DETI and Hope. Employee headcount is the basis for allocating other postretirement benefit costs and obligations between DETI 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 Energy uses December 31 as the measurement date for all of its employee benefit plans, including those in which Dominion Energy Gas participates. Dominion Energy 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 Energy 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 Dominion Energy’s pension and other postretirement benefit plans hold investments in trusts to fund employee benefit payments. Dominion Energy’s pension and other postretirement plan assets experienced aggregate actual returns (losses) of $(605) million and $1.6 billion in 2018 and 2017, respectively, versus expected returns of $806 million and $767 million, respectively. Dominion Energy Gas’ pension and other postretirement plan assets for employees represented by collective bargaining units experienced aggregate actual returns (losses) of $(129) million and $335 million in 2018 and 2017, respectively, versus expected returns of $178 million and $165 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. During 2016, Dominion Energy and Dominion Energy Gas (for employees represented by collective bargaining units) engaged their actuary to conduct an experience study of their employees demographics over a five-year period as compared to significant assumptions that were being used to determine pension and other postretirement benefit obligations and periodic costs. These assumptions primarily included mortality, retirement rates, termination rates, and salary increase rates. The changes in assumptions implemented as a result of the experience study resulted in increases of $290 million and $38 million in the pension and other postretirement benefits obligations, respectively, at December 31, 2016 for Dominion Energy and $24 million and $9 million in the pension and other postretirement benefits obligations, respectively, at December 31, 2016 for Dominion Energy Gas. In addition, these changes increased net periodic benefit costs $42 million for Dominion Energy during 2017. The increase in net periodic benefit costs for Dominion Energy Gas during 2017 was immaterial. P LAN MENDMENTS AND EMEASUREMENTS In the fourth quarter of 2017, Dominion Energy remeasured its pension and other postretirement benefit plans as a result of voluntary and involuntary separation programs at Dominion Energy Questar. The settlement and related remeasurement resulted in a reduction in the pension benefit obligation of approximately $75 million and an increase in the accumulated postretirement benefit obligation of approximately $2 million. The discount rates used for the 2017 pension cost and related settlement were 4.46% as of December 31, 2016, 4.51% as of January 31, 2017 and 4.05% as of June 30 and September 30, 2017. All other assumptions used were consistent with the measurement as of December 31, 2016. In the first quarter of 2017, Dominion Energy and Dominion Energy Gas remeasured an other postretirement benefit plan as a result of an amendment that changed post-65 Also during the first quarter of 2017, Dominion Energy recorded a $7 million ($4 million after-tax) after-tax) In the third quarter of 2016, Dominion Energy remeasured an other postretirement benefit plan as a result of an amendment that changed post-65 F UNDED TATUS 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 Energy and Dominion Energy Gas (for employees represented by collective bargaining units): Pension Benefits Other Postretirement Benefits Year Ended December 31, 2018 2017 2018 2017 (millions, except percentages) Dominion Energy Changes in benefit obligation: Benefit obligation at beginning of year $ 9,052 $ 8,132 $ 1,529 $ 1,478 Service cost 157 138 27 26 Interest cost 337 345 56 60 Benefits paid (358 ) (323 ) (87 ) (83 ) Actuarial (gains) losses during the year (688 ) 830 (158 ) 119 Plan amendments (1) — 5 (4 ) (73 ) Settlements and curtailments (2) — (75 ) — 2 Benefit obligation at end of year $ 8,500 $ 9,052 $ 1,363 $ 1,529 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 8,062 $ 7,016 $ 1,729 $ 1,512 Actual return (loss) on plan assets (513 ) 1,327 (92 ) 236 Employer contributions 6 118 12 13 Benefits paid (358 ) (323 ) (68 ) (32 ) Settlements (2) — (76 ) — — Fair value of plan assets at end of year $ 7,197 $ 8,062 $ 1,581 $ 1,729 Funded status at end of year $ (1,303 ) $ (990 ) $ 218 $ 200 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 1,003 $ 1,117 $ 276 $ 261 Other current liabilities (34 ) (8 ) (2 ) — Noncurrent pension and other postretirement benefit liabilities (2,272 ) (2,099 ) (56 ) (61 ) Net amount recognized $ (1,303 ) $ (990 ) $ 218 $ 200 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.42%–4.43% 3.80%–3.81% 4.37%–4.38% 3.76% Weighted average rate of increase for compensation 4.32% 4.09% 4.30%-4.55% 3.95%-4.11% Dominion Energy Gas Changes in benefit obligation: Benefit obligation at beginning of year $ 773 $ 683 $ 290 $ 320 Service cost 18 15 4 4 Interest cost 29 30 11 12 Benefits paid (34 ) (33 ) (18 ) (19 ) Actuarial (gains) losses during the year (56 ) 78 (27 ) 34 Plan amendments (1) — — (4 ) (61 ) Benefit obligation at end of year $ 730 $ 773 $ 256 $ 290 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 1,803 $ 1,542 $ 333 $ 299 Actual return (loss) on plan assets (113 ) 294 (16 ) 41 Employer contributions — — 12 12 Benefits paid (34 ) (33 ) (18 ) (19 ) Fair value of plan assets at end of year $ 1,656 $ 1,803 $ 311 $ 333 Funded status at end of year $ 926 $ 1,030 $ 55 $ 43 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 926 $ 1,030 $ 63 $ 57 Noncurrent pension and other postretirement benefit liabilities (3) — — (8 ) (14 ) Net amount recognized $ 926 $ 1,030 $ 55 $ 43 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.42 % 3.81 % 4.37 % 3.76 % Weighted average rate of increase for compensation 4.55 % 4.11 % n/a n/a (1) 2017 amounts relate primarily to a plan amendment that changed post-65 (2) 2017 amount relates primarily to settlement and curtailment as a result of the voluntary and involuntary separation programs at Dominion Energy Questar. (3) Reflected in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. The ABO for all of Dominion Energy’s defined benefit pension plans was $7.8 billion and $8.2 billion at December 31, 2018 and 2017, respectively. The ABO for the defined benefit pension plans covering Dominion Energy Gas employees represented by collective bargaining units was $689 million and $724 million at December 31, 2018 and 2017, respectively. Under its funding policies, Dominion Energy 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 Energy determines the amount of contributions for the current year, if any, at that time. During 2018, Dominion Energy and Dominion Energy Gas made no contributions to the qualified defined benefit pension plans. Dominion Energy expects to make $21 million of the minimum required contributions in 2019, and no contributions are currently expected in 2019 for Dominion Energy Gas. 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 Energy’s subsidiaries, including Dominion Energy Gas, fund other postretirement benefit costs through VEBAs. Dominion Energy’s remaining subsidiaries do not prefund other postretirement benefit costs but instead pay claims as presented. Dominion Energy’s contributions to VEBAs, all of which pertained to Dominion Energy Gas employees, totaled $12 million for both 2018 and 2017, and Dominion Energy expects to contribute approximately $12 million to the Dominion Energy VEBAs in 2019, all of which pertains to Dominion Energy Gas employees. Dominion Energy and Dominion Energy Gas do not expect any pension or other postretirement plan assets to be returned during 2019. 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 Energy and Dominion Energy Gas (for employees represented by collective bargaining units): Pension Benefits Other Postretirement Benefits As of December 31, 2018 2017 2018 2017 (millions) Dominion Energy Benefit obligation $ 7,705 $ 8,209 $164 $191 Fair value of plan assets 5,398 6,103 136 156 Dominion Energy Gas Benefit obligation $ — $ — $134 $157 Fair value of plan assets — — 126 143 The following table provides information on the ABO and fair value of plan assets for Dominion Energy’s pension plans with an ABO in excess of plan assets: As of December 31, 2018 2017 (millions) Accumulated benefit obligation $ 7,056 $ 7,392 Fair value of plan assets 5,398 6,103 The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) plans: Estimated Future Benefit Payments Pension Benefits Other Postretirement Benefits (millions) Dominion Energy 2019 $407 $98 2020 405 99 2021 426 99 2022 442 99 2023 465 98 2024-2028 2,548 461 Dominion Energy Gas 2019 $37 $19 2020 39 19 2021 40 19 2022 42 19 2023 43 19 2024-2028 223 90 P LAN SSETS Dominion Energy’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 Energy, Dominion Energy Gas is subject to Dominion Energy’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 Energy’s pension funds are 28% U.S. equity, 18% non-U.S. large-cap, mid-cap small-cap Non-U.S. large-cap small-cap non-U.S. Dominion Energy 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 Energy’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 Energy’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 Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) pension plan assets by asset category are as follows: At December 31, 2018 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 17 $ 1 $— $ 18 $ 18 $ — $— $ 18 Common and preferred stocks: U.S. 1,645 — — 1,645 1,902 — — 1,902 International 1,061 — — 1,061 1,151 — — 1,151 Insurance contracts — 318 — 318 — 352 — 352 Corporate debt instruments 23 729 — 752 41 729 — 770 Government securities 25 605 — 630 9 676 — 685 Total recorded at fair value $ 2,771 $ 1,653 $— $ 4,424 $ 3,121 $ 1,757 $— $ 4,878 Assets recorded at NAV (1) Common/collective trust funds 1,849 2,272 Alternative investments: Real estate funds 108 111 Private equity funds 633 606 Debt funds 155 161 Hedge funds 17 19 Total recorded at NAV $ 2,762 $ 3,169 Total investments (2) $ 7,186 $ 8,047 Dominion Energy Gas Cash and cash equivalents $ 4 $ — $— $ 4 $ 4 $ — $— $ 4 Common and preferred stocks: U.S. 378 — — 378 425 — — 425 International 244 — — 244 257 — — 257 Insurance contracts — 73 — 73 — 79 — 79 Corporate debt instruments 5 168 — 173 9 163 — 172 Government securities 6 139 — 145 2 151 — 153 Total recorded at fair value $ 637 $ 380 $— $ 1,017 $ 697 $ 393 $— $ 1,090 Assets recorded at NAV (1) Common/collective trust funds 425 509 Alternative investments: Real estate funds 25 25 Private equity funds 146 135 Debt funds 36 36 Hedge funds 4 4 Total recorded at NAV $ 636 $ 709 Total investments (3) $ 1,653 $ 1,799 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $12 million, net accrued income of $21 million, and includes net assets related to pending purchases of securities of $22 million at December 31, 2018. Excludes net assets related to pending sales of securities of $11 million, net accrued income of $19 million, and includes net assets related to pending purchases of securities of $15 million at December 31, 2017. (3) Excludes net assets related to pending sales of securities of $3 million, net accrued income of $5 million, and includes net assets related to pending purchases of securities of $5 million at December 31, 2018. Excludes net assets related to pending sales of securities of $3 million, net accrued income of $4 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2017. The fair values of Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) other postretirement plan assets by asset category are as follows: At December 31, 2018 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $1 $1 $— $ 2 $1 $2 $— $3 Common and preferred stocks: U.S. 554 — — 554 636 — — 636 International 170 — — 170 196 — — 196 Insurance contracts — 19 — 19 — 21 — 21 Corporate debt instruments 1 44 — 45 2 44 — 46 Government securities 2 37 — 39 1 41 — 42 Total recorded at fair value $728 $101 $— $ 829 $836 $108 $— $944 Assets recorded at NAV (1) Common/collective trust funds 650 689 Alternative investments: Real estate funds 10 9 Private equity funds 80 73 Debt funds 10 11 Hedge funds 1 1 Total recorded at NAV $ 751 $783 Total investments (2) $ 1,580 $1,727 Dominion Energy Gas Common and preferred stocks: U.S. $113 $— $— $ 113 $130 $— $— $130 International 30 — — 30 33 — — 33 Total recorded at fair value $143 $— $— $ 143 $163 $— $— $163 Assets recorded at NAV (1) Common/collective trust funds 148 154 Alternative investments: Real estate funds 2 1 Private equity funds 18 15 Debt funds — — Total recorded at NAV $ 168 $170 Total investments $ 311 $333 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2018. Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $1 million at December 31, 2017. The Plan’s investments are determined based on the fair values of the investments and the underlying investments, which have been determined as follows: • Cash and Cash Equivalents • Common and Preferred Stocks • Insurance Contracts • Corporate Debt Instruments • Government Securities • Common/Collective Trust Funds • Alternative Investments N ET ERIODIC ENEFIT REDIT OST The service cost component and non-service Pension Benefits Other Postretirement Benefits Year Ended December 31, 2018 2017 2016 2018 2017 2016 (millions, except percentages) Dominion Energy Service cost $ 157 $ 138 $ 118 $ 27 $ 26 $ 31 Interest cost 337 345 317 56 60 65 Expected return on plan assets (663 ) (639 ) (573 ) (143 ) (128 ) (118 ) Amortization of prior service (credit) cost 1 1 1 (52 ) (51 ) (35 ) Amortization of net actuarial loss 193 162 111 11 13 8 Settlements and curtailments — — 1 — — — Net periodic benefit (credit) cost $ 25 $ 7 $ (25 ) $ (101 ) $ (80 ) $ (49 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 490 $ 142 $ 931 $ 78 $ 12 $ 178 Prior service (credit) cost — 5 — (4 ) (73 ) (216 ) Settlements and curtailments — 1 (1 ) — 2 — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (193 ) (162 ) (111 ) (11 ) (13 ) (8 ) Amortization of prior service credit (cost) (1 ) (1 ) (1 ) 52 51 35 Total recognized in other comprehensive income and regulatory assets and liabilities $ 296 $ (15 ) $ 818 $ 115 $ (21 ) $ (11 ) Significant assumptions used to determine periodic cost: Discount rate 3.80%-3.8 1% 3.31%-4.5 0% 2.87%-4.9 9% 3.76% 3.92%-4.4 7% 3.56%-4.9 4% Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % Weighted average rate of increase for compensation 4.09 % 4.09 % 4.22 % 3.95%-4.1 1% 3.29 % 4.22 % Healthcare cost trend rate (1) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate (1)(2) 2022 2021 2020 Dominion Energy Gas Service cost $ 18 $ 15 $ 13 $ 4 $ 4 $ 5 Interest cost 29 30 30 11 12 14 Expected return on plan assets (150 ) (141 ) (134 ) (28 ) (24 ) (23 ) Amortization of prior service (credit) cost — — — (4 ) (3 ) 1 Amortization of net actuarial loss 19 16 13 3 2 1 Net periodic benefit (credit) cost $ (84 ) $ (80 ) $ (78 ) $ (14 ) $ (9 ) $ (2 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 207 $ (75 ) $ 91 $ 16 $ 18 $ 28 Prior service cost — — — (4 ) (61 ) — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (19 ) (16 ) (13 ) (3 ) (2 ) (1 ) Amortization of prior service credit (cost) — — — 4 3 (1 ) Total recognized in other comprehensive income and regulatory assets and liabilities $ 188 $ (91 ) $ 78 $ 13 $ (42 ) $ 26 Significant assumptions used to determine periodic cost: Discount rate 3.81 % 4.50 % 4.99 % 3.81 % 4.47 % 4.93 % Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % Weighted average rate of increase for compensation 4.11 % 4.11 % 3.93 % 4.55 % 4.11 % 3.93 % Healthcare cost trend rate (1) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate (1) 2022 2021 2020 (1) Assumptions used to determine net periodic cost for the following year. (2) The Society of Actuaries model used to determine healthcare cost trend rates was updated in 2014. The new model converges to the ultimate trend rate much more quickly than previous models. The components of AOCI and regulatory assets and liabilities for Dominion Energy and Dominion Energy 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, 2018 2017 2018 2017 (millions) Dominion Energy Net actuarial loss $ 3,477 $ 3,181 $ 350 $ 283 Prior service (credit) cost 7 8 (393 ) (440 ) Total (1) $ 3,484 $ 3,189 $ (43 ) $ (157 ) Dominion Energy Gas Net actuarial loss $ 555 $ 367 $ 89 $ 76 Prior service (credit) cost — — (52 ) (52 ) Total (2) $ 555 $ 367 $ 37 $ 24 (1) As of December 31, 2018, of the $3.5 billion and $(43) million related to pension benefits and other postretirement benefits, $2.0 billion and $(41) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2017, of the $3.2 billion and $(157) million related to pension benefits and other postretirement benefits, $1.9 billion and $(87) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. (2) As of December 31, 2018, of the $555 million related to pension benefits, $200 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $37 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2017, of the $367 million related to pension benefits, $134 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $24 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. The following table provides the components of AOCI and regulatory assets and liabilities for Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) plans as of December 31, 2018 that are expected to be amortized as components of net periodic benefit (credit) cost in 2019: Pension Benefits Other Benefits (millions) Dominion Energy Net actuarial loss $155 $ 18 Prior service (credit) cost 1 (52) Dominion Energy Gas Net actuarial loss $ 19 $ 4 Prior service (credit) cost — (4 ) The expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates and mortality are critical assumptions in determining net periodic benefit (credit) cost. Dominion Energy develops non-investment Dominion Energy determines the expected long-term rates of return on plan assets for its pension plans and other postretirement benefit plans, including those in which Dominion Energy Gas participates, by using a combination of: • Expected inflation and risk-free interest rate assumptions; • Historical return analysis to determine long term historic returns as well as historic risk premiums for various asset classes; • Expected future risk premiums, asset classes’ volatilities and correlations; • Forward-looking return expectations derived from the yield on long-term bonds and the expected long-term returns of major capital market assumptions; and • Investment allocation of plan assets. Dominion Energy determines discount rates from analyses of AA/Aa rated bonds with cash flows matching the expected payments to be made under its plans, including those in which Dominion Energy Gas participates. Mortality rates are developed from actual and projected plan experience for postretirement benefit plans. Dominion Energy’s actuary conducts an experience study periodically as part of the process to select its best estimate of mortality. Dominion Energy considers both standard mortality tables and improvement factors as well as the plans’ actual experience when selecting a best estimate. During 2016, Dominion Energy conducted a new experience study as scheduled and, as a result, updated its mortality assumptions for all its plans, including those in which Dominion Energy Gas participates. Assumed healthcare cost trend rates have a significant effect on the amounts reported for Dominion Energy’s retiree healthcare plans, including those in which Dominion Energy Gas participates. A one percentage point change in assumed healthcare cost trend rates would have had the following effects for Dominion Energy and Dominion Energy 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 Energy Effect on net periodic cost for 2019 $ 20 $ (16) Effect on other postretirement benefit obligation at December 31, 2018 130 (110) Dominion Energy Gas Effect on net periodic cost for 2019 $ 4 $ (3) Effect on other postretirement benefit obligation at December 31, 2018 25 (22) Dominion Energy Gas (Employees Not Represented by Collective Bargaining Units) and Virginia Power—Participation in Defined Benefit Plans Virginia Power employees and Dominion Energy Gas employees not represented by collective bargaining units are covered by the Dominion Energy Pension Plan described above. As participating employers, Virginia Power and Dominion Energy Gas are subject to Dominion Energy’s funding policy, which is to contribute annually an amount that is in accordance with ERISA. During 2018, Virginia Power and Dominion Energy Gas made no contributions to the Dominion Energy Pension Plan, and no contributions to this plan are currently expected in 2019. Virginia Power’s net periodic pension cost related to this plan was $126 million, $110 million and $79 million in 2018, 2017 and 2016, respectively. Dominion Energy Gas’ net periodic pension credit related to this plan was $(38) million, $(37) million and $(45) million in 2018, 2017 and 2016, respectively. Net periodic pension (credit) cost is reflected in other operations and maintenance expense in their respective Consolidated Statements of Income. The funded status of various Dominion Energy subsidiary groups and employee compensation are the basis for determining the share of total pension costs for participating Dominion Energy subsidiaries. See Note 24 for Virginia Power and Dominion Energy Gas amounts due to/from Dominion Energy related to this plan. Retiree healthcare and life insurance benefits, for Virginia Power employees and for Dominion Energy Gas employees not represented by collective bargaining units, are covered by the Dominion Energy Retiree Health and Welfare Plan described above. Virginia Power’s net periodic benefit (credit) cost related to this plan was $(51) million, $(42) million and $(29) million in 2018, 2017 and 2016, respectively. Dominion Energy Gas’ net periodic benefit (credit) cost related to this plan was $(7) million, $(5) million and $(4) million for 2018, 2017 and 2016, respectively. Net periodic benefit (credit) cost is reflected in other operations and maintenance expenses in their respective Consolidated Statements of Income. Employee headcount is the basis for determining the share of total other postretirement benefit costs for participating Dominion Energy subsidiaries. See Note 24 for Virginia Power and Dominion Energy Gas amounts due to/from Dominion Energy related to this plan. Dominion Energy holds investments in trusts to fund employee benefit payments for the pension and other postretirement benefit plans in which Virginia Power and Dominion Energy Gas’ employees participate. Any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash that Virginia Power and Dominion Energy Gas will provide to Dominion Energy for their shares of employee benefit plan contributions. Certain regulatory authorities have held that amounts recovered in rates for other postretirement benefits, in excess of benefits actually paid during the year, must be deposited in trust funds dedicated for the sole purpose of paying such benefits. Accordingly, Virginia Power and Dominion Energy Gas fund other postretirement benefit costs through VEBAs. During 2018 and 2017, Virginia Power made no contributions to the VEBA and does not expect to contribute to the VEBA in 2019. Dominion Energy Gas made no contributions to the VEBAs for employees not represented by collective bargaining units during 2018 and 2017 and does not expect to contribute in 2019. Defined Con

Commitments And Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	N OTE OMMITMENTS ND 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 that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations that 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 Companies’ financial position, liquidity or results of operations. 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 The MATS rule requires coal- and oil-fired In June 2017, the DOE issued an order to PJM to direct Virginia Power to operate Yorktown power station’s Units 1 and 2 as needed to avoid reliability issues on the Virginia Peninsula. The order was effective for 90 days and can be reissued upon PJM’s request, if necessary, until required electricity transmission upgrades are completed. Beginning in August 2017, PJM filed requests for 90-day In December 2018, the EPA issued a proposed rule to reverse its previous finding that it is appropriate and necessary to regulate toxic emissions from power plants. However, the emissions standards and other requirements of the MATS rule would remain in place as the EPA is not proposing to remove coal and oil fired power plants from the list of sources that are regulated under MATS. Although litigation of the MATS rule and the outcome of the EPA’s rulemaking are still pending, the regulation remains in effect and Virginia Power is complying with the applicable requirements of the rule and does not expect any adverse impacts to its operations at this time. Ozone Standards In October 2015, the EPA issued a final rule tightening the ozone standard from 75-ppb 70-ppb. X X X mid-2019 X non-catalytic X gas-fired The EPA published final non-attainment NO x In April 2016, the Pennsylvania Department of Environmental Protection issued final regulations, with an effective date of January 2017, to reduce NO X Oil and Gas NSPS In August 2012, the EPA issued an NSPS impacting new and modified facilities in 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 June 2016, the EPA issued a new NSPS regulation, for the oil and natural gas sector, to regulate methane and VOC emissions from new and modified facilities in transmission and storage, gathering and boosting, production and processing facilities. All projects which commenced construction after September 2015 are required to comply with this regulation. In October 2018, the EPA published a proposed rule reconsidering and amending portions of the 2016 rule, including but not limited to, the fugitive emissions requirements at well sites and compressor stations. Until the proposed rule is final, Dominion Energy and Dominion Energy Gas are implementing the 2016 regulation. Dominion Energy and Dominion Energy Gas are still evaluating whether potential impacts on results of operations, financial condition and/or cash flows related to this matter will be material. GHG R EGULATION Carbon Regulations In August 2016, the EPA issued a draft rule proposing to reaffirm that a source’s obligation to obtain a PSD or Title V permit for GHGs is triggered only if such permitting requirements are first triggered by non-GHG, 2 In addition, the EPA continues to evaluate its policy regarding the consideration of CO 2 Methane Emissions In July 2015, the EPA announced the next generation of its voluntary Natural Gas STAR Program, the Natural Gas STAR Methane Challenge Program. The 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. In March 2016, East Ohio, Hope, DETI and Questar Gas joined the EPA as founding partners in the new Methane Challenge program and submitted implementation plans in September 2016. Wexpro, DECG and Dominion Energy Questar Pipeline joined the Methane Challenge in 2018. DECG joined the EPA’s voluntary Natural Gas STAR Program in July 2016 and submitted an implementation plan in September 2016 with Questar Gas and Dominion Energy Questar Pipeline joining in 2018. Dominion Energy and Dominion Energy Gas do not expect the costs related to these programs to have a material impact on their results of operations, financial condition and/or cash flows. 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 case-by-case 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. In April 2017, the EPA granted two separate petitions for reconsideration of the Effluent Limitations Guidelines final rule and stayed future compliance dates in the rule. Also in April 2017, the U.S. Court of Appeals for the Fifth Circuit granted the U.S.’s request for a stay of the pending consolidated litigation challenging the rule while the EPA addresses the petitions for reconsideration. In September 2017, the EPA signed a rule to postpone the earliest compliance dates for certain waste streams regulations in the Effluent Limitations Guidelines final rule from November 2018 to November 2020; however, the latest date for compliance for these regulations remains December 2023. The EPA is proposing to complete new rulemaking for these waste streams. While the impacts of this rule could be material to Dominion Energy and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory frameworks in South Carolina and Virginia provide rate recovery mechanisms that could substantially mitigate any such impacts for Dominion Energy and Virginia Power. W ASTE ANAGEMENT AND EMEDIATION 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 From time to time, Dominion Energy, Virginia Power, or Dominion Energy 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. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion Energy, Virginia Power, or Dominion Energy 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. The Companies do not believe these matters will have a material effect on results of operations, financial condition and/or cash flows. Dominion Energy has determined that it is associated with 22 former manufactured gas plant sites, three of which pertain to Virginia Power and 12 of which pertain to Dominion Energy 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 Energy is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. In addition, a Virginia Power site has been accepted into a state-based voluntary remediation program. In June 2018, Virginia Power submitted a proposed remedial action plan to remove material from this site at an estimated cost of $18 million. Pending VDEQ approval, Virginia Power expects to begin remedial work at this site in mid-2019. after-tax) 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. A PPALACHIAN ATEWAY Pipeline Contractor Litigation Following the completion of the Appalachian Gateway project in 2012, DETI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2015, the contractor filed a complaint against DETI in U.S. District Court for the Western District of Pennsylvania. In March 2016, the Pennsylvania court granted DETI’s motion to transfer the case to the U.S. District Court for the Eastern District of Virginia. In July 2016, DETI filed a motion to dismiss. In March 2017, the court dismissed three of eight counts in the complaint. In May 2017, the contractor withdrew one of the counts in the complaint. In November 2017, DETI and the contractor entered into a partial settlement agreement for a release of certain claims. In August 2018, DETI paid $14 million in accordance with the terms of a settlement agreement reached between the parties, resolving this matter. Gas Producers Litigation In connection with the Appalachian Gateway project, Dominion Energy Field Services, Inc. entered into contracts for firm purchase rights with a group of small gas producers. In June 2016, the gas producers filed a complaint in the Circuit Court of Marshall County, West Virginia against Dominion Energy, DETI and Dominion Energy Field Services, Inc., among other defendants, claiming that the contracts are unenforceable and seeking compensatory and punitive damages. During the third quarter of 2016, Dominion Energy, DETI and Dominion Energy Field Services, Inc. were served with the complaint. Also in the third quarter of 2016, Dominion Energy and DETI, with the consent of the other defendants, removed the case to the U.S. District Court for the Northern District of West Virginia. In October 2016, the defendants filed a motion to dismiss and the plaintiffs filed a motion to remand. In February 2017, the U.S. District Court entered an order remanding the matter to the Circuit Court of Marshall County, West Virginia. In March 2017, Dominion Energy was voluntarily dismissed from the case; however, DETI and Dominion Energy Field Services, Inc. remain parties to the matter. In April 2017, the case was transferred to the Business Court Division of West Virginia. In January 2018, the court granted the motion to dismiss filed by the defendants on two counts. Claims are pending in the Business Court Division of West Virginia. Dominion Energy and Dominion Energy Gas cannot currently estimate financial statement impacts, but there could be a material impact to their financial condition and/or cash flows. A SH OND AND ANDFILL LOSURE OSTS In March 2015, the Sierra Club filed a lawsuit alleging CWA violations at Chesapeake power station. In March 2017, the U.S. District Court for the Eastern District of Virginia ruled that impacted groundwater associated with the on-site on-site In April 2015, the EPA enacted a final rule regulating CCR landfills, existing ash ponds that still receive and manage CCRs, and inactive ash ponds that do not receive, but still store, CCRs. Dominion Energy currently operates inactive ash ponds, existing ash ponds and CCR landfills subject to the final rule at 11 different facilities, eight of which are at Virginia Power. This rule created a legal obligation for Dominion Energy and 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. In 2016, Virginia Power recorded an increase to this ARO of $238 million, which resulted in a $197 million incremental charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $17 million increase in property, plant and equipment and a $24 million increase in regulatory assets. In December 2016, legislation was enacted that creates a framework for EPA- In April 2017, the Governor of Virginia signed legislation into law that places a moratorium on the VDEQ issuing solid waste permits for closure of ash ponds at Virginia Power’s Bremo, Chesapeake, Chesterfield and Possum Point power stations until May 2018. The law also required Virginia Power to conduct an assessment of closure alternatives for the ash ponds at these four stations, to include an evaluation of excavation for recycling or off-site on-site, after-tax) C OVE OINT In September 2014, FERC issued an order granting authorization for Cove Point to construct, modify and operate the Liquefaction Project at the Cove Point facility, which enables the facility to liquefy domestically-produced natural gas and export it as LNG. In March 2018, Cove Point received authorization from FERC to commence service of the Liquefaction Project, which commenced commercial operations in April 2018. 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 were consolidated. In July 2016, the court denied one party’s petition for review of the FERC order authorizing the Liquefaction Project. The court also issued a decision remanding the other party’s petition for review of the FERC order to FERC for further explanation of FERC’s decision that a previous transaction with an existing import shipper was not unduly discriminatory. In September 2017, FERC issued its order on remand from the U.S. Court of Appeals for the D.C. Circuit, and reaffirmed its ruling in its prior orders that Cove Point did not violate the prohibition against undue discrimination by agreeing to a capacity reduction and early contract termination with the existing import shipper. In October 2017, the party filed a request for rehearing of the FERC order on remand. In August 2018, FERC issued its rehearing order affirming and clarifying its previous orders. No appeals were filed and FERC’s orders are final and no longer subject to further review. FERC FERC staff in the Office of Enforcement, Division of Investigations, conducted a non-public day-ahead 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 the Institute of Nuclear Power Operations. Like other U.S. nuclear operators, Dominion Energy 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 Energy 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 Nuclear Operations N UCLEAR ECOMMISSIONING INIMUM INANCIAL SSURANCE 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 2018 calculation for the NRC minimum financial assurance amount, aggregated for Dominion Energy 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 $2.7 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 2018 NRC minimum financial assurance amounts above were calculated using preliminary December 31, 2018 U.S. Bureau of Labor Statistics indices. Dominion Energy 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 Energy 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. N UCLEAR NSURANCE The Price-Anderson Amendments Act of 1988 provides the public with liability protection on a per site, per nuclear incident basis, via obligations required of owners of nuclear power plants, and allows for an inflationary provision adjustment every five years. During the second quarter of 2018, the total liability protection per nuclear incident available to all participants in the Secondary Financial Protection Program decreased from $13.4 billion to $13.1 billion. During the fourth quarter of 2018, this amount increased from $13.1 billion to $14.1 billion. Dominion Energy and Virginia Power have purchased $450 million of coverage from commercial insurance pools for Millstone, Surry and North Anna with the remainder provided through the mandatory industry retrospective rating plan. In the event of a nuclear incident at any licensed nuclear reactor in the U.S., Dominion Energy and Virginia Power could be assessed up to $138 million for each of their licensed reactors not to exceed $21 million per year per reactor. There is no limit to the number of incidents for which this retrospective premium can be assessed. The NRC granted an exemption in March 2015 to remove Kewaunee from the Secondary Financial Protection program. This same exemption permitted Dominion Energy to reduce Kewaunee’s required level of liability coverage to $100 million. This reduction was implemented in January 2018, following the removal and storage of the spent nuclear fuel from the spent fuel pool. The current levels of nuclear property insurance coverage for Dominion Energy and Virginia Power’s nuclear units are as follows: Coverage (billions) Dominion Energy Millstone $ 1.70 Kewaunee 0.05 Virginia Power (1) Surry $ 1.70 North Anna 1.70 (1) Surry and North Anna share a blanket property limit of $200 million. Dominion Energy and Virginia Power’s nuclear property insurance coverage for Millstone, Surry and North Anna exceeds the NRC minimum requirement for nuclear power plant licensees of $1.06 billion per reactor site. In March 2015, the NRC granted an exemption which allowed Kewaunee to reduce its property insurance limit to $50 million. This reduction was implemented in January 2018, following the removal and storage of the spent nuclear fuel from the spent fuel pool. This includes coverage for premature decommissioning and functional total loss. The NRC requires that the proceeds from this insurance be used first, to return the reactor to and maintain it in a safe and stable condition and second, to decontaminate the reactor and station site in accordance with a plan approved by the NRC. Nuclear property insurance is provided by NEIL, a mutual insurance company, and is subject to retrospective premium assessments in any policy year in which losses exceed the funds available to the insurance company. Dominion Energy and Virginia Power’s maximum retrospective premium assessment for the current policy period is $83 million and $51 million, respectively. Based on the severity of the incident, the Board of Directors of the nuclear insurer has the discretion to lower or eliminate the maximum retrospective premium assessment. Dominion Energy and Virginia Power have the financial responsibility for any losses that exceed the limits or for which insurance proceeds are not available because they must first be used for stabilization and decontamination. Millstone and Virginia Power also purchase accidental outage insurance from NEIL to mitigate certain expenses, including replacement power costs, associated with the prolonged outage of a nuclear unit due to direct physical damage. Under this program, Dominion Energy and Virginia Power are subject to a retrospective premium assessment for any policy year in which losses exceed funds available to NEIL. Dominion Energy and Virginia Power’s maximum retrospective premium assessment for the current policy period is $21 million and $10 million, respectively. ODEC, a part owner of North Anna, and Massachusetts Municipal and Green Mountain, part owners of Millstone’s Unit 3, are responsible to Dominion Energy and Virginia Power for their share of the nuclear decommissioning obligation and insurance premiums on applicable units, including any retrospective premium assessments and any losses not covered by insurance. S PENT UCLEAR UEL Dominion Energy and Virginia Power entered into contracts with the DOE for the disposal of spent nuclear fuel under provisions of the Nuclear Waste Policy Act of 1982. The DOE failed to begin accepting the spent fuel on January 31, 1998, the date provided by the Nuclear Waste Policy Act and by Dominion Energy and Virginia Power’s contracts with the DOE. Dominion Energy and Virginia Power have previously received damages award payments and settlement payments related to these contracts. By mutual agreement of the parties, the settlement agreements are extendable to provide for resolution of damages incurred after 2013. The settlement agreements for the Surry, North Anna and Millstone nuclear power stations have been extended to provide for periodic payments for damages incurred through December 31, 2019. In June 2018, a lawsuit for Kewaunee was filed in the U.S. Court of Federal Claims for recovery of spent nuclear fuel storage costs incurred for the period January 1, 2014 through December 31, 2017. This matter is pending. In 2018, Virginia Power and Dominion Energy received payments of $16 million for resolution of claims incurred at North Anna and Surry for the period of January 1, 2016 through December 31, 2016, and $13 million for resolution of claims incurred at Millstone for the period of July 1, 2016 through June 30, 2017. In 2017, Virginia Power and Dominion Energy received payments of $22 million for resolution of claims incurred at North Anna and Surry for the period of January 1, 2015 through December 31, 2015, and $14 million for resolution of claims incurred at Millstone for the period of July 1, 2015 through June 30, 2016. In 2016, Virginia Power and Dominion Energy received payments of $30 million for resolution of claims incurred at North Anna and Surry for the period of January 1, 2014 through December 31, 2014, and $22 million for resolution of claims incurred at Millstone for the period of July 1, 2014 through June 30, 2015. Dominion Energy and Virginia Power continue to recognize receivables for certain spent nuclear fuel-related costs that they believe are probable of recovery from the DOE. Dominion Energy’s receivables for spent nuclear fuel-related costs totaled $49 million and $46 million at December 31, 2018 and 2017, respectively. Virginia Power’s receivables for spent nuclear fuel-related costs totaled $30 million at both December 31, 2018 and 2017. Dominion Energy and Virginia Power will continue to manage their spent fuel until it is accepted by the DOE. Long-Term Purchase Agreements At December 31, 2018, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that a third party has used to secure financing for the facility that will provide the contracted goods or services: 2019 2020 2021 2022 2023 Thereafter Total (millions) Purchased electric capacity (1) $ 60 $ 52 $ 46 $ — $ — $ — $ 158 (1) Commitments represent estimated amounts payable for capacity under power purchase contracts with independent power producers, which end 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, 2018, the present value of Virginia Power’s total commitment for capacity payments is $142 million. Capacity payments totaled $50 million, $114 million and $248 million, and energy payments totaled $42 million, $72 million and $126 million for the years ended 2018, 2017 and 2016, respectively. Lease Commitments The Companies lease real estate, vehicles and equipment primarily under operating leases. Payments under certain leases are escalated based on an index such as the consumer price index. Future minimum lease payments under noncancelable operating leases that have initial or remaining lease terms in excess of one year as of December 31, 2018 are as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions) Dominion Energy $ 64 $ 61 $ 55 $ 47 $ 38 $ 384 $ 649 Virginia Power 34 32 28 22 16 106 238 Dominion Energy Gas 12 11 9 7 4 3 46 Rental expense for Dominion Energy totaled $109 million, $113 million, and $104 million for 2018, 2017 and 2016, respectively. Rental expense for Virginia Power totaled $63 million, $57 million, and $52 million for 2018, 2017 and 2016, respectively. Rental expense for Dominion Energy Gas totaled $22 million, $34 million, and $37 million for 2018, 2017 and 2016, respectively. The majority of rental expense is reflected in other operations and maintenance expense in the Consolidated Statements of Income. In July 2016, Dominion Energy signed an agreement with a lessor to construct and lease a new corporate office property in Richmond, Virginia. The lessor is providing equity and has obtained financing commitments from debt investors, totaling $365 million, to fund the estimated project costs. The project is expected to be completed by mid-2019. The five-year lease term will commence once construction is substantially complete and the facility is able to be occupied. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an additional five years, subject to the approval of the participants, at current market terms, (ii) purchase the property for an amount equal to the project costs or, (iii) subject to certain terms and conditions, sell the property on behalf of the lessor to a t

Credit Risk

Credit Risk	12 Months Ended
	Dec. 31, 2018
Risks and Uncertainties [Abstract]
Credit Risk	N OTE REDIT 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, 2018 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 D OMINION NERGY As a diversified energy company, Dominion Energy 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, Dominion Energy’s exposure to credit risk is concentrated primarily within its energy marketing and price risk management activities, as Dominion Energy 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- off-balance non-investment V IRGINIA OWER 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- off-balance D OMINION NERGY AS Dominion Energy 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 on- off-balance non-investment In 2018, DETI provided service to 307 customers with approximately 96% of its storage and transportation revenue being provided through firm services. The ten largest customers provided approximately 38% of the total storage and transportation revenue and the thirty largest provided approximately 71% 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 99% 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 Energy’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion Energy to provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered as of December 31, 2018 and 2017, Dominion Energy would have been required to post an additional $1 million and $62 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

Related-Party Transactions

Related-Party Transactions	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related-Party Transactions	N OTE ELATED PARTY RANSACTIONS Virginia Power and Dominion Energy Gas engage in related party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia Power and Dominion Energy 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 Energy Gas are included in Dominion Energy’s consolidated federal income tax return and, where applicable, combined income tax returns for Dominion Energy are filed in various states. See Note 2 for further information. Dominion Energy’s transactions with equity method investments are described in Note 9. A discussion of significant related party transactions follows. V IRGINIA OWER 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 forward commodity purchases, to manage commodity price risks associated with purchases of natural gas. See Notes 7 and 19 for more information. As of December 31, 2018, Virginia Power’s derivative assets and liabilities with affiliates were $26 million and $10 million, respectively. As of December 31, 2017, Virginia Power’s derivative assets and liabilities with affiliates were $11 million and $5 million, respectively. Virginia Power participates in certain Dominion Energy benefit plans as described in Note 21. At December 31, 2018 and 2017, Virginia Power’s amounts due to Dominion Energy associated with the Dominion Energy Pension Plan and reflected in noncurrent pension and other postretirement benefit liabilities in the Consolidated Balance Sheets were $632 million and $505 million, respectively. At December 31, 2018 and 2017, Virginia Power’s amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $254 million and $199 million, respectively. DES 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. The financial statements for all years presented include costs for certain general, administrative and corporate expenses assigned by DES to Virginia Power on the basis of direct and allocated methods in accordance with Virginia Power’s services agreements with DES. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DES resources that is attributable to the entity, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DES service. Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. Presented below are significant transactions with DES and other affiliates: Year Ended December 31, 2018 2017 2016 (millions) Commodity purchases from affiliates $ 930 $ 674 $ 571 Services provided by affiliates (1) 450 453 454 Services provided to affiliates 24 25 22 (1) Includes capitalized expenditures of $145 million, $144 million and $144 million for the year ended December 31, 2018, 2017 and 2016, respectively. Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were $224 million and $33 million in short-term demand note borrowings from Dominion Energy as of December 31, 2018 and 2017, respectively. The weighted-average interest rate of these borrowings was 2.94% and 1.65% at December 31, 2018 and 2017, respectively. Virginia Power had no outstanding borrowings, net of repayments under the Dominion Energy money pool for its nonregulated subsidiaries as of December 31, 2018 and 2017. Interest charges related to Virginia Power’s borrowings from Dominion Energy were immaterial for the years ended December 31, 2018, 2017 and 2016. There were no issuances of Virginia Power’s common stock to Dominion Energy in 2018, 2017 or 2016. D OMINION NERGY AS Transactions with Related Parties Dominion Energy Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Energy Gas provides transportation and storage services to affiliates. Dominion Energy Gas also enters into certain other contracts with affiliates, and related parties, including construction services, which are presented separately from contracts involving commodities or services. As of December 31, 2018 and 2017, all of Dominion Energy Gas’ commodity derivatives were with affiliates. See Notes 7 and 19 for more information. See Note 9 for information regarding transactions with an affiliate. Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 21. At December 31, 2018 and 2017, Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Pension Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $772 million and $734 million, respectively. Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $14 million and $7 million at December 31, 2018 and 2017, respectively. DES and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Energy Gas. Dominion Energy Gas provides certain services to related parties, including technical services. The financial statements for all years presented include costs for certain general, administrative and corporate expenses assigned by DES to Dominion Energy Gas on the basis of direct and allocated methods in accordance with Dominion Energy Gas’ services agreements with DES. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DES resources that is attributable to the entity, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DES service. Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. The costs of these services follow: Year Ended December 31, 2018 2017 2016 (millions) Sales of natural gas and transportation and storage services to affiliates $ 58 $ 70 $ 69 Purchases of natural gas from affiliates 6 5 9 Services provided by related parties (1) 131 143 141 Services provided to related parties (2) 216 156 128 (1) Includes capitalized expenditures of $37 million, $45 million and $49 million for the year ended December 31, 2018, 2017 and 2016, respectively. (2) Amounts primarily attributable to Atlantic Coast Pipeline, a related party VIE. The following table presents affiliated and related party balances reflected in Dominion Energy Gas’ Consolidated Balance Sheets: At December 31, 2018 2017 (millions) Other receivables (1) $ 13 $ 12 Customer receivables from related parties 1 1 Imbalances receivable from affiliates 1 1 Imbalances payable to affiliates (2) 13 — Affiliated notes receivable (3) 16 20 (1) Represents amounts due from Atlantic Coast Pipeline, a related party VIE. (2) Amounts are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (3) Amounts are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. Dominion Energy Gas’ borrowings under the IRCA with Dominion Energy totaled $218 million and $18 million as of December 31, 2018 and 2017, respectively. The weighted-average interest rate of these borrowings was 2.78% and 1.60% at December 31, 2018 and 2017, respectively. Interest charges related to Dominion Energy Gas’ total borrowings from Dominion Energy were immaterial for 2018, 2017 and 2016.

Operating Segments

Operating Segments	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Operating Segments	N OTE PERATING 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 Description of Operations Dominion Virginia Dominion Power Delivery Regulated electric distribution X X Regulated electric transmission X X Power Generation Regulated electric generation fleet X X Merchant electric generation fleet X Gas Infrastructure Gas transmission and storage X (1) X Gas distribution and storage X X Gas gathering and processing X X LNG terminalling and storage X Nonregulated retail energy marketing X (1) Includes remaining producer services activities. In addition to the operating segments above, the Companies also report a Corporate and Other segment. D OMINION NERGY The Corporate and Other Segment of Dominion Energy In 2018, Dominion Energy reported after-tax The net expenses for specific items in 2018 primarily related to the impact of the following items: • A $219 million ($164 million after-tax) • A $215 million ($160 million after-tax) one-time • Power Generation ($109 million after-tax); • Power Delivery ($51 million after-tax); • A $170 million ($134 million after-tax) • A $124 million ($88 million after-tax) • An $81 million ($60 million after-tax) • A $70 million ($52 million after-tax) • An $828 million ($619 million after-tax) • Power Generation ($229 million after-tax); • Gas Infrastructure ($390 million after-tax). In 2017, Dominion Energy reported after-tax The net benefits for specific items in 2017 primarily related to the impact of the following items: • A $979 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act, primarily attributable to: • Gas Infrastructure ($324 million); • Power Generation ($655 million); partially offset by • $158 million ($96 million after-tax) In 2016, Dominion Energy reported after-tax The net expenses for specific items in 2016 primarily related to the impact of the following items: • A $197 million ($122 million after-tax) • A $59 million ($36 million after-tax) • Power Delivery ($5 million after-tax); • Gas Infrastructure ($12 million after-tax); • Power Generation ($19 million after-tax). The following table presents segment information pertaining to Dominion Energy’s operations: Year Ended December 31, Power Delivery Power Generation Gas Infrastructure Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2018 Total revenue from external customers $ 2,206 $ 7,104 $ 4,221 $ (208 ) $ 43 $ 13,366 Intersegment revenue 23 11 27 674 (735 ) — Total operating revenue 2,229 7,115 4,248 466 (692 ) 13,366 Depreciation, depletion and amortization 625 746 615 14 — 2,000 Impairment of assets and related charges — 1 8 394 — 403 Gains on sales of assets — 6 (186 ) (200 ) — (380 ) Equity in earnings of equity method investees — 18 178 1 — 197 Interest income — 90 64 126 (196 ) 84 Interest and related charges 265 374 268 782 (196 ) 1,493 Income tax expense (benefit) 160 294 330 (204 ) — 580 Net income (loss) attributable to Dominion Energy 587 1,254 1,214 (608 ) — 2,447 Investment in equity method investees — 82 1,159 37 — 1,278 Capital expenditures 1,564 1,321 1,415 105 — 4,405 Total assets (billions) 17.8 28.2 31.5 11.2 (10.8 ) 77.9 2017 Total revenue from external customers $ 2,206 $ 6,676 $ 2,832 $ 16 $ 856 $ 12,586 Intersegment revenue 22 10 834 610 (1,476 ) — Total operating revenue 2,228 6,686 3,666 626 (620 ) 12,586 Depreciation, depletion and amortization 593 747 522 43 — 1,905 Impairment of assets and related charges — — — 15 — 15 Gains on sales of assets — — (147 ) — — (147 ) Equity in earnings of equity method investees — (181 ) 159 4 — (18 ) Interest income 4 92 45 96 (155 ) 82 Interest and related charges 265 342 109 644 (155 ) 1,205 Income tax expense (benefit) 334 373 487 (1,224 ) — (30 ) Net income (loss) attributable to Dominion Energy 531 1,181 898 389 — 2,999 Investment in equity method investees — 81 1,422 41 — 1,544 Capital expenditures 1,433 2,275 2,149 52 — 5,909 Total assets (billions) 16.7 29.0 28.0 12.0 (9.1 ) 76.6 2016 Total revenue from external customers $ 2,210 $ 6,747 $ 2,069 $ (7 ) $ 718 $ 11,737 Intersegment revenue 23 10 697 609 (1,339 ) — Total operating revenue 2,233 6,757 2,766 602 (621 ) 11,737 Depreciation, depletion and amortization 537 662 330 30 — 1,559 Impairment of assets and related charges — — — 4 — 4 Gains on sales of assets — 4 (44 ) — — (40 ) Equity in earnings of equity method investees — (16 ) 105 22 — 111 Interest income — 74 34 36 (78 ) 66 Interest and related charges 244 290 38 516 (78 ) 1,010 Income tax expense (benefit) 308 279 431 (363 ) — 655 Net income (loss) attributable to Dominion Energy 484 1,397 726 (484 ) — 2,123 Capital expenditures 1,320 2,440 2,322 43 — 6,125 Intersegment sales and transfers for Dominion Energy are based on contractual arrangements and may result in intersegment profit or loss that is eliminated in consolidation. V IRGINIA OWER 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 Power Delivery and Power Generation segments. The Corporate and Other Segment of Virginia Power In 2018, Virginia Power reported an after-tax The net expenses for specific items in 2018 primarily related to the impact of the following items: • A $215 million ($160 million after-tax) one-time • Power Generation ($109 million after-tax); • Power Delivery ($51 million after-tax). • An $81 million ($60 million after-tax) • A $70 million ($52 million after-tax) In 2017, Virginia Power reported an after-tax The net benefit for specific items in 2017 primarily related to the impact of the following item: • A $93 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act, attributable to Power Generation. In 2016, Virginia Power reported after-tax The net expenses for specific items in 2016 primarily related to the impact of the following item: • A $197 million ($121 million after-tax) The following table presents segment information pertaining to Virginia Power’s operations: Year Ended December 31, Power Delivery Power Generation Corporate and Other Adjustments & Consolidated Total (millions) 2018 Operating revenue $ 2,204 $ 5,630 $ (215 ) $ — $ 7,619 Depreciation and amortization 624 533 (25 ) — 1,132 Interest income — 9 5 (4 ) 10 Interest and related charges 265 250 — (4 ) 511 Income tax expense (benefit) 158 220 (78 ) — 300 Net income (loss) 586 1,008 (312 ) — 1,282 Capital expenditures 1,539 1,003 — — 2,542 Total assets (billions) 17.6 19.4 — (0.1 ) 36.9 2017 Operating revenue $ 2,212 $ 5,344 $ — $ — $ 7,556 Depreciation and amortization 594 547 — — 1,141 Interest income 4 15 3 (3 ) 19 Interest and related charges 265 232 — (3 ) 494 Income tax expense (benefit) 334 534 (94 ) — 774 Net income 527 939 74 — 1,540 Capital expenditures 1,439 1,290 — — 2,729 Total assets (billions) 16.6 18.6 — (0.1 ) 35.1 2016 Operating revenue $ 2,217 $ 5,390 $ (19 ) $ — $ 7,588 Depreciation and amortization 537 488 — — 1,025 Interest income — — — — — Interest and related charges 244 219 — (2 ) 461 Income tax expense (benefit) 307 524 (104 ) — 727 Net income (loss) 482 909 (173 ) — 1,218 Capital expenditures 1,313 1,336 — — 2,649 D OMINION NERGY AS The Corporate and Other Segment of Dominion Energy Gas In 2018, Dominion Energy Gas reported after-tax The net expenses for specific items in 2018 primarily related to the impact of the following items: • A $219 million ($165 million after-tax) • A $124 million ($88 million after-tax) In 2017, Dominion Energy Gas reported after-tax The net benefit for specific items in 2017 primarily related to the impact of the following item: • A $185 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act. In 2016, Dominion Energy Gas reported after-tax The net expense for specific items in 2016 primarily related to the impact of the following item: • An $8 million ($5 million after-tax) The following table presents segment information pertaining to Dominion Energy Gas’ operations: Year Ended December 31, Gas Infrastructure Corporate and Other Consolidated Total (millions) 2018 Operating revenue $ 1,940 $ — $ 1,940 Depreciation and amortization 244 — 244 Impairment of assets and related charges 5 341 346 Gains on sales of assets (119 ) — (119 ) Equity in earnings of equity method investees 24 — 24 Interest income 2 — 2 Interest and related charges 104 1 105 Income tax expense (benefit) 188 (102 ) 86 Net income (loss) 552 (251 ) 301 Investment in equity method investees 91 — 91 Capital expenditures 772 — 772 Total assets (billions) 11.8 0.6 12.4 2017 Operating revenue $ 1,814 $ — $ 1,814 Depreciation and amortization 227 — 227 Impairment of assets and related charges 15 1 16 Gains on sales of assets (70 ) — (70 ) Equity in earnings of equity method investees 21 — 21 Interest income 2 — 2 Interest and related charges 97 — 97 Income tax expense (benefit) 256 (205 ) 51 Net income 436 179 615 Investment in equity method investees 95 — 95 Capital expenditures 778 — 778 Total assets (billions) 11.3 0.6 11.9 2016 Operating revenue $ 1,638 $ — $ 1,638 Depreciation and amortization 214 (10 ) 204 Gains on sales of assets (45 ) — (45 ) Equity in earnings of equity method investees 21 — 21 Interest income 1 — 1 Interest and related charges 92 2 94 Income tax expense (benefit) 237 (22 ) 215 Net income (loss) 395 (3 ) 392 Capital expenditures 854 — 854

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	N OTE UARTERLY INANCIAL ATA NAUDITED A summary of the Companies’ quarterly results of operations for the years ended December 31, 2018 and 2017 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. D OMINION NERGY First Second Third Fourth (millions) 2018 Operating revenue $ 3,466 $ 3,088 $ 3,451 $ 3,361 Income from operations 875 742 1,150 834 Net income including noncontrolling interests 526 478 883 662 Net income attributable to Dominion Energy 503 449 854 641 Basic EPS: Net income attributable to Dominion Energy 0.77 0.69 1.31 0.97 Diluted EPS: Net income attributable to Dominion Energy 0.77 0.69 1.30 0.97 Dividends declared per common share 0.835 0.835 0.835 0.835 2017 Operating revenue $ 3,384 $ 2,813 $ 3,179 $ 3,210 Income from operations 1,079 753 1,152 953 Net income including noncontrolling interests 674 417 696 1,333 Net income attributable to Dominion Energy 632 390 665 1,312 Basic EPS: Net income attributable to Dominion Energy 1.01 0.62 1.03 2.04 Diluted EPS: Net income attributable to Dominion Energy 1.01 0.62 1.03 2.04 Dividends declared per common share 0.755 0.755 0.770 0.770 Dominion Energy’s 2018 results include the impact of the following significant items: • Fourth quarter results include $536 million of after-tax after-tax • Second quarter results include an $89 million after-tax • First quarter results include a $160 million after-tax one-time Dominion Energy’s 2017 results include the impact of the following significant item: • Fourth quarter results include $851 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act, partially offset by $96 million of after-tax V IRGINIA OWER Virginia Power’s quarterly results of operations were as follows: First Second Third Fourth (millions) 2018 Operating revenue $ 1,748 $ 1,829 $ 2,232 $ 1,810 Income from operations 364 533 756 418 Net income 184 339 520 239 2017 Operating revenue $ 1,831 $ 1,747 $ 2,154 $ 1,824 Income from operations 653 613 847 619 Net income 356 318 459 407 Virginia Power’s 2018 results include the impact of the following significant item: • First quarter results include a $160 million after-tax one-time Virginia Power’s 2017 results include the impact of the following significant item: • Fourth quarter results include a $93 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act. D OMINION NERGY AS Dominion Energy Gas’ quarterly results of operations were as follows: First Second Third Fourth (millions) 2018 Operating revenue $526 $459 $423 $532 Income (loss) from operations 201 7 182 (55 ) Net income (loss) 166 15 136 (16) 2017 Operating revenue $490 $422 $401 $501 Income from operations 156 116 185 181 Net income 108 77 117 313 Dominion Energy Gas’s 2018 results include the impact of the following significant items: • Fourth quarter results include a $165 million after-tax • Second quarter results include an $89 million after-tax Dominion Energy Gas’s 2017 results include the impact of the following significant item: • Fourth quarter results include a $197 million tax benefit resulting from the remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act.

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Estimates	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.
Consolidation	The Companies’ Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned
Consolidation, consolidated entities and noncontrolling interest	For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. At December 31, 2018, Dominion Energy 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. In August 2018, NRG’s ownership interest in Four Brothers and Three Cedars was transferred to GIP. GIP’s ownership interest in Four Brothers and Three Cedars, Terra Nova Renewable Partners’ 33% interest in certain of Dominion Energy’s merchant solar projects and the non-Dominion
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 Energy and Virginia Power collect sales, consumption and consumer utility taxes and Dominion Energy Gas collects sales taxes; however, these amounts are excluded from revenue. Dominion Energy’s customer receivables at December 31, 2018 and 2017 included $626 million and $661 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, 2018 and 2017 included $392 million and $400 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. Dominion Energy Gas’ customer receivables at December 31, 2018 and 2017 included $131 million and $121 million, respectively, of accrued unbilled revenue based on estimated amounts of natural gas delivered but not yet billed to its customers. See Note 24 for amounts attributable to related parties. The primary types of sales and service activities reported as operating revenue for Dominion Energy, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated electric sales • Nonregulated electric sales • Regulated gas sales • Nonregulated gas sales • Regulated gas transportation and storage sales • Nonregulated gas transportation and storage sales • Other regulated revenue • Other nonregulated revenue O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated electric sales • Nonregulated electric sales • Regulated gas sales • Nonregulated gas sales • Gas transportation and storage sales • Other revenue The primary types of sales and service activities reported as operating revenue for Virginia Power, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated electric sales • Other regulated revenue • Other nonregulated revenue non-jurisdictional O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Virginia Power, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated electric sales • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: R EVENUE FROM ONTRACTS WITH USTOMERS • Regulated gas sales • Nonregulated gas sales • Regulated gas transportation and storage sales • NGL revenue • Management service revenue • Other regulated revenue • Other nonregulated revenue O THER EVENUE • Other revenue The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows: • Regulated gas sales • Nonregulated gas sales • Gas transportation and storage sales • NGL revenue • Other revenue Dominion Energy and Virginia Power record refunds to customers as required by state commissions as a reduction to regulated electric sales or regulated gas sales, as applicable. Dominion Energy and Virginia Power’s revenue accounted for under the alternative revenue program guidance primarily consists of the equity return for under-recovery of certain riders. Alternative revenue programs compensate Dominion Energy and Virginia Power for certain projects and initiatives. Revenues arising from these programs are presented separately from revenue arising from contracts with customers in the categories above. Revenues from electric and gas sales are recognized over time, as the customers of the Companies consume gas and electricity as it is delivered. Transportation and storage contracts are primarily stand-ready service contracts that include fixed reservation and variable usage fees. LNG terminalling services are also stand-ready service contracts, primarily consisting of fixed fees, offset by service credits associated with the start-up Dominion Energy and Dominion Energy Gas typically receive or retain NGLs and natural gas from customers when providing natural gas processing, transportation or storage services. The revised guidance for revenue from contracts with customers requires entities to include the fair value of the noncash consideration in the transaction price. Therefore, subsequent to the adoption of the revised guidance for revenue recognition from contracts with customers, Dominion Energy and Dominion Energy Gas record the fair value of NGLs received during natural gas processing as service revenue recognized over time, and continue to recognize revenue from the subsequent sale of the NGLs to customers upon delivery. Dominion Energy and Dominion Energy Gas typically retain natural gas under certain transportation service arrangements that are intended to facilitate performance of the service and allow for natural losses that occur. As the intent of the allowance is to enable fulfillment of the contract rather than to provide compensation for services, the fuel allowance is not included in revenue.
Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Where permitted by regulatory authorities, the differences between Dominion Energy and Virginia Power’s actual electric fuel and purchased energy expenses and Dominion Energy and Dominion Energy 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, at December 31, 2018, approximately 84% is subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms. Virtually all of Dominion Energy Gas, Cove Point, Questar Gas, Hope and SCE&G and PSNC’s, following the SCANA Combination, 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 Energy and its subsidiaries, including Virginia Power and Dominion Energy Gas’ subsidiaries. In addition, where applicable, combined income tax returns for Dominion Energy and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Although Dominion Energy 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 Energy. Virginia Power and Dominion Energy Gas participate in intercompany tax sharing agreements with Dominion Energy 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 Energy consolidated group members. Otherwise, the net operating loss or credit is carried forward and is recognized as a deferred tax asset until realized. The 2017 Tax Reform Act included a broad range of tax reform provisions affecting the Companies, including changes in corporate tax rates and business deductions. The 2017 Tax Reform Act reduces the corporate income tax rate from 35% to 21% for tax years beginning after December 31, 2017. Deferred tax assets and liabilities are classified as noncurrent in the Consolidated Balance Sheets and measured at the enacted tax rate expected to apply when temporary differences are realized or settled. Thus, at the date of enactment, federal deferred taxes were remeasured based upon the new 21% tax rate. The total effect of tax rate changes on deferred tax balances was recorded as a component of the income tax provision related to continuing operations for the period in which the law is enacted, even if the assets and liabilities relate to other components of the financial statements, such as items of accumulated other comprehensive income. For Dominion Energy subsidiaries that are not rate-regulated utilities, existing deferred income tax assets or liabilities were adjusted for the reduction in the corporate income tax rate and allocated to continuing operations. Dominion Energy’s rate-regulated utility subsidiaries likewise were required to adjust deferred income tax assets and liabilities for the change in income tax rates. However, if it is probable that the effect of the change in income tax rates will be recovered or refunded in future rates, the regulated utility recorded a regulatory asset or liability instead of an increase or decrease to deferred income tax expense. 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 The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not If it is not more-likely-than-not 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. Interest for the Companies was immaterial in 2018 and 2016. Dominion Energy and Virginia Power both recognized interest income of $11 million in 2017. Dominion Energy Gas’ interest was immaterial in 2017. Dominion Energy, Virginia Power and Dominion Energy Gas’ penalties were immaterial in 2018, 2017 and 2016. At December 31, 2018, Virginia Power had an income tax-related In addition, Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2018 included $13 million of state income taxes receivable. State income taxes receivable at Virginia Power were immaterial at December 31, 2018. At December 31, 2017, Virginia Power had an income tax-related In addition, Virginia Power’s Consolidated Balance Sheet at December 31, 2017 included $1 million of noncurrent federal income taxes receivable, less than $1 million of state income taxes receivable and $1 million of noncurrent state income taxes receivable. Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 included $14 million of state income taxes receivable. Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
Cash, Restricted Cash and Equivalents	Cash, Restricted Cash and Equivalents Cash, restricted cash and equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less. 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: At December 31, 2018 2017 (millions) Dominion Energy $ 35 $ 30 Virginia Power 16 17 Dominion Energy Gas 7 7 R ESTRICTED ASH AND QUIVALENTS The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for customer deposits, future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements and on Eagle Solar’s senior note agreement. The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2018, 2017 and 2016: Cash, Restricted Cash and Equivalents at December 31, December 31, December 31, December 31, (millions) Dominion Energy Cash and cash equivalents $ 268 $ 120 $ 261 $ 607 Restricted cash and equivalents (1) 123 65 61 25 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 391 $ 185 $ 322 $ 632 Virginia Power Cash and cash equivalents $ 29 $ 14 $ 11 $ 18 Restricted cash and equivalents (1) 9 10 — — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 38 $ 24 $ 11 $ 18 Dominion Energy Gas Cash and cash equivalents $ 10 $ 4 $ 23 $ 13 Restricted cash and equivalents (1) 24 26 20 14 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 34 $ 30 $ 43 $ 27 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets. D ISTRIBUTIONS FROM QUITY ETHOD NVESTEES Dominion Energy and Dominion Energy Gas each hold investments that are accounted for under the equity method of accounting. Dominion Energy and Dominion Energy Gas classify distributions from equity method investees as either cash flows from operating activities or cash flows from investing activities in the Consolidated Statements of Cash Flows according to the nature of the distribution. Distributions received are classified on the basis of the nature of the activity of the investee that generated the distribution as either a return on investment (classified as cash flows from operating activities) or a return of an investment (classified as cash flows from investing activities) when such information is available to Dominion Energy and Dominion Energy Gas.
Derivative Instruments	Derivative Instruments 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 and foreign currency exchange rate risks of their business operations. Dominion Energy uses derivative instruments such as physical and financial forwards, futures, swaps, options and FTRs to manage the commodity, interest rate and foreign currency exchange rate risks of its business operations. Virginia Power uses derivative instruments such as physical and financial forwards, futures, swaps, options and FTRs to manage commodity and interest rate risks. Dominion Energy Gas uses derivative instruments such as physical and financial forwards, futures and swaps to manage commodity, interest rate and foreign currency exchange 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 Energy had margin assets of $95 million and $92 million associated with cash collateral at December 31, 2018 and 2017, respectively. Dominion Energy’s margin liabilities associated with cash collateral were less than $1 million at December 31, 2018 and 2017. Virginia Power had margin assets of $23 million associated with cash collateral at December 31, 2017. Virginia Power had no margin assets associated with cash collateral at December 31, 2018 and no margin liabilities associated with cash collateral at December 31, 2018 and 2017. Dominion Energy Gas had no margin assets or liabilities associated with cash collateral at December 31, 2018 and 2017. See Note 7 for further information about derivatives. To manage price risk, the Companies hold certain derivative instruments that are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices. All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses, interest and related charges or other income based on the nature of the underlying risk. 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 NSTRUMENTS ESIGNATED AS EDGING NSTRUMENTS In accordance with accounting guidance pertaining to derivatives and hedge accounting, the Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. 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 Dominion Energy entered into interest rate derivative instruments to hedge its forecasted interest payments related to planned debt issuances in 2014. These interest rate derivatives were designated by Dominion Energy as cash flow hedges prior to the formation of Dominion Energy Gas. For the purposes of the Dominion Energy Gas financial statements, the derivative balances, AOCI balance, and any income statement impact related to these interest rate derivative instruments entered into by Dominion Energy have been, and will continue to be, included in the Dominion Energy Gas’ Consolidated Financial Statements as the forecasted interest payments related to the debt issuances now occur at Dominion Energy Gas. Fair Value Hedges
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 In 2018, 2017 and 2016, Dominion Energy capitalized interest costs and AFUDC to property, plant and equipment of $134 million, $236 million and $159 million, respectively. In 2018, 2017 and 2016, Virginia Power capitalized AFUDC to property, plant and equipment of $56 million, $37 million and $21 million, respectively. In 2018, 2017 and 2016, Dominion Energy Gas capitalized AFUDC to property, plant and equipment of $18 million, $25 million and $8 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 2018, 2017 and 2016, Virginia Power recorded $4 million, $22 million and $31 million of AFUDC related to these projects, respectively. For property subject to cost-of-service cost-of-service plant-in-service after-tax) For property that is not subject to cost-of-service 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, 2018 2017 2016 (percent) Dominion Energy Generation 2.71 2.94 2.83 Transmission 2.54 2.55 2.47 Distribution 2.97 3.00 3.02 Storage 2.40 2.48 2.29 Gas gathering and processing 2.62 2.21 2.66 General and other 4.56 4.89 4.12 Virginia Power Generation 2.71 2.94 2.83 Transmission 2.52 2.54 2.36 Distribution 3.31 3.32 3.32 General and other 4.52 4.68 3.49 Dominion Energy Gas Transmission 2.45 2.40 2.43 Distribution 2.41 2.42 2.55 Storage 2.46 2.45 2.19 Gas gathering and processing 3.07 2.42 2.58 General and other 5.59 4.96 4.54 In the second quarter of 2018, Virginia Power recorded an adjustment for the retroactive application of depreciation rates for regulated nuclear plants to comply with Virginia Commission requirements. This adjustment resulted in a decrease of $60 million ($44 million after-tax) after-tax). In the first quarter of 2017, Virginia Power revised the depreciation rates for its assets to reflect the results of a new depreciation study. This change resulted in an increase in annual depreciation expense of $40 million ($25 million after-tax) after-tax) Capitalized costs of development wells and leaseholds are amortized on a field-by-field unit-of-production Dominion Energy’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 15-30 years Nonutility gas gathering and processing 3-50 LNG facility 40 years General and other 5-59 Depreciation and amortization related to Virginia Power and Dominion Energy Gas’ nonutility property, plant and equipment and exploration and production properties was immaterial for the years ended December 31, 2018, 2017 and 2016, except for Dominion Energy Gas’ nonutility gas gathering and processing properties which are depreciated using the straight-line method over estimated useful lives between 10 and 50 years. Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production
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.
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities The accounting for Dominion Energy and Dominion Energy Gas’ regulated gas and Dominion Energy 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 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, for which a legal obligation exists. 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. Quarterly, the Companies assess their AROs to determine if circumstances indicate that estimates of the amounts or timing of future cash flows associated with retirement activities have changed. AROs are adjusted when significant changes in the amounts or timing of future cash flows are identified. Dominion Energy and Dominion Energy 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. Dominion Energy, following the SCANA Combination, and Virginia Power report 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, Dominion Energy and Virginia Power report accretion of AROs and depreciation on asset retirement costs associated with certain rider and 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 a reduction in long-term debt 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. 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.
Investments	Investments D EBT AND QUITY ECURITIES WITH EADILY ETERMINABLE AIR ALUES Dominion Energy accounts for and classifies investments in debt securities as trading or available-for-sale available-for-sale • Debt securities classified as trading securities • Debt securities classified as available-for-sale available-for-sale after-tax. In determining realized gains and losses for debt securities, the cost basis of the security is based on the specific identification method. Equity securities with readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the nuclear decommissioning trusts. Dominion Energy and Virginia Power record all equity securities with a readily determinable fair value, or for which they are permitted to estimate fair value using NAV (or its equivalent), at fair value in nuclear decommissioning trust funds and other investments in the Consolidated Balance Sheets. However, Dominion Energy and Virginia Power may elect a measurement alternative for equity securities without a readily determinable fair value. Under the measurement alternative, equity securities are reported at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. Dominion Energy and Virginia Power qualitatively assess equity securities reported using the measurement alternative to determine whether an investment is impaired on an ongoing basis. Net realized and unrealized gains and losses on equity securities 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 equity securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts and rabbi trusts, net realized and unrealized gains and losses are included in other income in the Consolidated Statements of Income. E QUITY ECURITIES WITHOUT EADILY ETERMINABLE AIR ALUES The Companies account for illiquid and privately held securities without readily determinable fair values under either the equity method or cost method. Equity securities without readily determinable fair values include: • Equity method investments • Cost method investments O THER HAN EMPORARY MPAIRMENT The Companies periodically review their investments in debt securities and equity method investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in the 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 for Debt Securities • The recognition provisions of other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale held-to-maturity. • Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion Energy 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 non-performance
Inventories	Inventories Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory is valued using the weighted-average cost method, except for East Ohio gas distribution operations, which are valued using the LIFO method. Under the LIFO method, current stored gas inventory was valued at $12 million and $9 million at December 31, 2018 and December 31, 2017, respectively. Based on the average price of gas purchased during 2018 and 2017, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by $87 million and $79 million, respectively.
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 Energy and Dominion Energy 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.
Goodwill	Goodwill Dominion Energy and Dominion Energy 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
New Accounting Standards	New Accounting Standards R EVENUE ECOGNITION In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The Companies adopted this revised accounting guidance for interim and annual reporting periods beginning January 1, 2018 using the modified retrospective method. Upon the adoption of the standard, Dominion Energy and Dominion Energy Gas recorded the cumulative-effect of a change in accounting principle of $3 million to retained earnings and membership interests, respectively, and to establish a contract asset related to changes in the timing of revenue recognition for three existing contracts with customers at DETI. As a result of adopting this revised accounting guidance, Dominion Energy and Dominion Energy Gas record offsetting operating revenue and other energy-related purchases for non-cash F INANCIAL NSTRUMENTS In January 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of financial instruments. The guidance became effective for the Companies’ interim and annual reporting periods beginning January 1, 2018 and the Companies adopted the standard using the modified retrospective method. Upon adoption of this guidance for equity securities held at January 1, 2018, Dominion Energy and Virginia Power recorded the cumulative-effect of a change in accounting principle to reclassify net unrealized gains from AOCI to retained earnings and to recognize equity securities previously categorized as cost method investments at fair value (using NAV) in nuclear decommissioning trust funds in the Consolidated Balance Sheets and a cumulative-effect adjustment to retained earnings. Dominion Energy and Virginia Power reclassified approximately $1.1 billion ($734 million after-tax) after-tax), after-tax) after-tax) after-tax) L EASES In February 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of leasing arrangements. The update requires that a liability and corresponding right-of-use The guidance is effective for the Companies’ interim and annual reporting periods beginning January 1, 2019. The Companies will adopt this revised accounting guidance using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the date of adoption. Under this approach, the Companies are permitted to utilize the transition practical expedient to maintain historical presentation for periods before January 1, 2019. The Companies will apply the other practical expedients, which would require no reassessment of whether existing contracts are or contain leases, no reassessment of lease classification for existing leases and no reassessment of existing or expired land easements that were not previously accounted for as leases. Dominion Energy, Virginia Power and Dominion Energy Gas anticipate that the adoption of this guidance will result in approximately $450 million to $500 million, $200 million to $250 million and $60 million to $70 million, respectively, of offsetting right-of-use right-of-use D ERECOGNITION AND ARTIAL ALES OF ONFINANCIAL SSETS In February 2017, the FASB issued revised accounting guidance clarifying the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The guidance became effective for the Companies’ interim and annual reporting periods beginning January 1, 2018, and the Companies adopted the standard using the modified retrospective method. Upon adoption of the standard, Dominion Energy recorded the cumulative-effect of a change in accounting principle to reclassify $127 million from noncontrolling interests to common stock related to the sale of a noncontrolling interest in certain merchant solar projects completed in December 2015 and January 2016. N ET ERIODIC ENSION AND THER OSTRETIREMENT ENEFIT OSTS In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic pension and other postretirement benefit costs. This guidance became effective for the Companies beginning January 1, 2018 and requires that the service cost component of net periodic pension and other postretirement benefit costs be classified in the same line item as other compensation costs arising from services rendered by employees, while all other components of net periodic pension and other postretirement costs are classified outside of income from operations. In addition, only the service cost component remains eligible for capitalization during construction. These changes do not impact the accounting by participants in a multi-employer plan. The standard also recognizes that in the event that a regulator continues to require capitalization of all net periodic benefit costs prospectively, the difference would result in recognition of a regulatory asset or liability. For costs not capitalized for which regulators are expected to provide recovery, a regulatory asset will be established. As such, the amounts eligible for capitalization in the Consolidated Financial Statements of Virginia Power and Dominion Energy Gas, as subsidiary participants in Dominion Energy’s multi-employer plans, will differ from the amounts eligible for capitalization in the Consolidated Financial Statements of Dominion Energy, the plan administrator. These differences will result in a regulatory asset or liability recorded in the Consolidated Financial Statements of Dominion Energy. T AX EFORM In December 2017, the staff of the SEC issued guidance which clarifies accounting for income taxes if information is not yet available or complete and provided for up to a one-year tax-related In August 2018, the U.S. Department of Treasury issued proposed regulations addressing the availability of federal bonus depreciation for the period beginning after September 27, 2017 through December 31, 2017. The application of these changes decreased Dominion Energy’s net operating loss carryforward utilization on its 2017 tax return as discussed in Note 5. In November 2018, the U.S. Department of Treasury issued proposed regulations defining interest as any amounts associated with the time value of money or use of funds. These proposed regulations provide guidance for purposes of the exception to the interest limitation for regulated public utilities, the application of the interest limitation to consolidated groups, such as Dominion Energy, and the interest limitation with respect to partnerships and partners in those partnerships. It is unclear when the guidance may be finalized, or whether that guidance could result in a disallowance of a portion of the Companies’ interest deductions in the future. In February 2018, the FASB issued revised accounting guidance to provide clarification on the application of the 2017 Tax Reform Act for balances recorded within AOCI. The revised guidance provides for stranded amounts within AOCI from the impacts of the 2017 Tax Reform Act to be reclassified to retained earnings. The Companies adopted this guidance for interim and annual reporting periods beginning January 1, 2018 on a prospective basis. In connection with the adoption of this guidance, Dominion Energy reclassified a benefit of $289 million from AOCI to retained earnings, Virginia Power reclassified a benefit of $3 million from AOCI to retained earnings and Dominion Energy Gas reclassified a benefit of $26 million from AOCI to membership interests. The amounts reclassified reflect the reduction in the federal income tax rate, and the federal benefit of state income taxes, on the components of the Companies’ AOCI.
Fair Value Measurements	Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. However, the use of a mid-market mid-point Inputs and Assumptions 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 industry publications, and to a lesser extent, broker quotes. When evaluating pricing information provided by Designated Contract Market settlement pricing, other pricing services, or brokers, the Companies consider the ability to transact at the quoted price, i.e. if the quotes are based on an active market or an inactive market and to the extent which pricing models are used, 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 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 sources. For options and contracts with option-like characteristics where observable pricing information is not available from external sources, Dominion Energy 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 Energy and Virginia Power use other option models under special circumstances, including but not limited to Spread Approximation Model and a Swing Option Model. 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 • Notional value • Credit enhancements • Time value For foreign currency derivative contracts: • Foreign currency forward exchange rates • Interest rates • Credit quality of counterparties and the Companies • Notional value • Credit enhancements • Time value For investments: • Quoted securities prices and indices • Securities trading information including volume and restrictions • Maturity • Interest rates • Credit quality 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, U.S. and international equity securities, mutual funds and certain Treasury securities held in nuclear decommissioning trust funds for Dominion Energy and Virginia Power, benefit plan trust funds for Dominion Energy and Dominion Energy Gas, and rabbi trust funds for Dominion Energy. • 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, foreign currency swaps and cash and cash equivalents, corporate debt instruments, government securities and other fixed income investments held in nuclear decommissioning trust funds for Dominion Energy and Virginia Power, benefit plan trust funds for Dominion Energy and Dominion Energy Gas and rabbi trust funds for Dominion Energy. • 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, certain natural gas and power options and other modeled commodity derivatives. 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. Alternative investments, consisting of investments in partnerships, joint ventures and other alternative investments held in nuclear decommissioning and benefit plan trust funds, 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. Alternative investments recorded at NAV are not classified in the fair value hierarchy. 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 Level 3 Valuations 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 mark-to-market
Regulatory Matters Involving Potential Loss Contingencies	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 regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that 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.
Dominion Energy and Dominion Energy Gas-Defined Benefit Plans	Dominion Energy and Dominion Energy Gas—Defined Benefit Plans Dominion Energy provides certain retirement benefits to eligible active employees, retirees and qualifying dependents. Dominion Energy Gas participates in a number of the Dominion Energy-sponsored retirement plans. Under the terms of its benefit plans, Dominion Energy 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 Energy 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 Energy’s funding policy is to contribute annually an amount that is in accordance with the provisions of ERISA. The pension programs also provide benefits to certain retired executives under company-sponsored nonqualified employee benefit plans. The nonqualified plans are funded through contributions to grantor trusts. Dominion Energy 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 Energy Gas employees not represented by collective bargaining units are covered by the Dominion Energy Pension Plan, a defined benefit pension plan sponsored by Dominion Energy that provides benefits to multiple Dominion Energy subsidiaries. Pension benefits for Dominion Energy Gas employees represented by collective bargaining units are covered by separate pension plans for East Ohio and, for DETI, a plan that provides benefits to employees of both DETI and Hope. Employee compensation is the basis for allocating pension costs and obligations between DETI and Hope and determining East Ohio’s share of total pension costs. Retiree healthcare and life insurance benefits for Dominion Energy Gas employees not represented by collective bargaining units are covered by the Dominion Energy Retiree Health and Welfare Plan, a plan sponsored by Dominion Energy that provides certain retiree healthcare and life insurance benefits to multiple Dominion Energy subsidiaries. Retiree healthcare and life insurance benefits for Dominion Energy Gas employees represented by collective bargaining units are covered by separate other postretirement benefit plans for East Ohio and, for DETI, a plan that provides benefits to both DETI and Hope. Employee headcount is the basis for allocating other postretirement benefit costs and obligations between DETI 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 Energy uses December 31 as the measurement date for all of its employee benefit plans, including those in which Dominion Energy Gas participates.
Commitments and Contingencies	As a result of issues generated in the ordinary course of business, the Companies are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations that 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 Companies’ financial position, liquidity or results of operations.
Guarantees, Surety Bonds and Letters of Credit	Dominion Energy also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion Energy would be obligated to satisfy such obligation. To the extent that a liability subject to a guarantee has been incurred by one of Dominion Energy’s consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion Energy is not required to recognize liabilities for guarantees issued on behalf of its subsidiaries unless it becomes probable that it will have to perform under the guarantees. Terms of the guarantees typically end once obligations have been paid. Dominion Energy currently believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries’ obligations.
Indemnifications	Indemnifications As part of commercial contract negotiations in the normal course of business, the Companies may sometimes agree to make payments to compensate or indemnify other parties for possible future unfavorable financial consequences resulting from specified events. The specified events may involve an adverse judgment in a lawsuit or the imposition of additional taxes due to a change in tax law or interpretation of the tax law. The Companies are unable to develop an estimate of the maximum potential amount of any other future payments under these contracts because events that would obligate them have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence. However, at December 31, 2018, the Companies believe any other future payments, if any, that could ultimately become payable under these contract provisions, would not have a material impact on their results of operations, cash flows or financial position.
Credit Risk	Credit risk 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, 2018 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.

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2018
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: At December 31, 2018 2017 (millions) Dominion Energy $ 35 $ 30 Virginia Power 16 17 Dominion Energy Gas 7 7
Reconciliation of Total Cash, Restricted Cash and Equivalents	The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2018, 2017 and 2016: Cash, Restricted Cash and Equivalents at December 31, December 31, December 31, December 31, (millions) Dominion Energy Cash and cash equivalents $ 268 $ 120 $ 261 $ 607 Restricted cash and equivalents (1) 123 65 61 25 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 391 $ 185 $ 322 $ 632 Virginia Power Cash and cash equivalents $ 29 $ 14 $ 11 $ 18 Restricted cash and equivalents (1) 9 10 — — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 38 $ 24 $ 11 $ 18 Dominion Energy Gas Cash and cash equivalents $ 10 $ 4 $ 23 $ 13 Restricted cash and equivalents (1) 24 26 20 14 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 34 $ 30 $ 43 $ 27 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.
Schedule of Depreciation Rates	The Companies’ average composite depreciation rates on utility property, plant and equipment are as follows: Year Ended December 31, 2018 2017 2016 (percent) Dominion Energy Generation 2.71 2.94 2.83 Transmission 2.54 2.55 2.47 Distribution 2.97 3.00 3.02 Storage 2.40 2.48 2.29 Gas gathering and processing 2.62 2.21 2.66 General and other 4.56 4.89 4.12 Virginia Power Generation 2.71 2.94 2.83 Transmission 2.52 2.54 2.36 Distribution 3.31 3.32 3.32 General and other 4.52 4.68 3.49 Dominion Energy Gas Transmission 2.45 2.40 2.43 Distribution 2.41 2.42 2.55 Storage 2.46 2.45 2.19 Gas gathering and processing 3.07 2.42 2.58 General and other 5.59 4.96 4.54
Property, Plant and Equipment	Dominion Energy’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 15-30 years Nonutility gas gathering and processing 3-50 LNG facility 40 years General and other 5-59

Acquisitions And Dispositions (

Acquisitions And Dispositions (Tables)	12 Months Ended
	Dec. 31, 2018
Business Acquisition, Pro Forma Information	The following unaudited pro forma financial information reflects the consolidated results of operations of Dominion Energy assuming the SCANA Combination had taken place on January 1, 2018. The unaudited pro forma financial information has been presented for illustrative purposes only and may change as Dominion Energy finalizes its valuation of certain assets acquired and liabilities assumed at the acquisition date. The unaudited pro forma financial information is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of the combined company. Twelve Months Ended December 31, 2018 (1) (millions, except EPS) Operating Revenue $ 17,505 Net income attributable to Dominion Energy 2,081 Earnings Per Common Share – Basic $ 2.78 Earnings Per Common Share – Diluted $ 2.77 (1) Amounts include adjustments for non-recurring
Schedule of Business Acquisitions, by Acquisition	The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion Energy. Completed Acquisition Seller Number of Project Location Project Name(s) Initial (1) Project (2) Date of MW February 2017 Community Energy Solar, LLC 1 Virginia Amazon Solar Farm $ 29 $ 205 December 2017 100 March 2017 Solar Frontier Americas 1 (3) California Midway II 77 78 June 2017 30 May 2017 Cypress Creek Renewables, 1 North Carolina IS37 154 160 June 2017 79 June 2017 Hecate Energy Virginia C&C 1 Virginia Clarke County 16 16 August 2017 10 June 2017 Strata Solar Development, 2 North Carolina Fremont, Moorings 2 20 20 November 2017 10 September 2017 Hecate Energy Virginia C&C 1 Virginia Cherrydale 40 41 November 2017 20 October 2017 Strata Solar 2 North Carolina Clipperton, Pikeville 20 21 November 2017 10 (1) The purchase price was primarily allocated to Property, Plant and Equipment. (2) Includes acquisition cost. (3) In April 2017, Dominion Energy discontinued efforts on the acquisition of the additional 20 MW solar project from Solar Frontier Americas Holding LLC.
SCANA
Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed	The table below shows the preliminary allocation of the purchase price to the assets acquired and liabilities assumed at closing to be reflected in Dominion Energy’s Consolidated Balance Sheet in the first quarter of 2019. The allocation is subject to change during the measurement period as additional information is obtained about the facts and circumstances that existed at closing. The allocation of the purchase price excludes certain contracts and intangible assets related to nonregulated operations, including SEMI, equity method investments and certain income tax-related Amount (millions) Total current assets $ 1,756 Investments 213 Property, plant and equipment, net 10,982 Goodwill 2,438 Regulatory assets 4,219 Other deferred charges and other assets, including intangible assets 314 Total Assets 19,922 Total current liabilities 1,506 Long-term debt 6,707 Deferred income taxes 1,097 Regulatory liabilities 2,664 Other deferred credits and other liabilities 1,109 Total Liabilities 13,083 Total purchase price $ 6,839
Business Acquisition, Pro Forma Information	The following unaudited pro forma financial information reflects the consolidated results of operations of Dominion Energy assuming the Dominion Energy Questar Combination had taken place on January 1, 2016. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of the combined company. Twelve 2016 (1) (millions, except EPS) Operating Revenue $ 12,497 Net income attributable to Dominion Energy 2,300 Earnings Per Common Share – Basic $ 3.73 Earnings Per Common Share – Diluted $ 3.73 (1) Amounts include adjustments for non-recurring
Dominion Energy Questar Corporation
Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed	The modifications relate primarily to the finalization of Dominion Energy Questar’s 2016 tax return for the period January 1, 2016 through the Dominion Energy Questar Combination, as well as certain regulatory adjustments. Amount (millions) Total current assets $ 224 Investments (1) 58 Property, plant and equipment, net (2) 4,131 Goodwill 3,111 Total deferred charges and other assets, excluding goodwill 75 Total Assets 7,599 Total current liabilities (3) 793 Long-term debt (4) 963 Deferred income taxes 807 Regulatory liabilities 259 Asset retirement obligations 160 Other deferred credits and other liabilities 220 Total Liabilities 3,202 Total purchase price 4,397 (1) Includes $40 million for an equity method investment in White River Hub. The fair value adjustment on the equity method investment in White River Hub is considered to be equity method goodwill and is not amortized. (2) Nonregulated property, plant and equipment, excluding land, will be depreciated over remaining useful lives primarily ranging from 9 to 18 years. (3) Includes $301 million of short-term debt, of which no amounts remain outstanding at December 31, 2018, as well as a $250 million variable interest rate term loan due in August 2017 that was paid in July 2017. (4) Unsecured senior and medium-term notes with maturities which range from 2017 to 2048 and bear interest at rates from 2.98% to 7.20%.

Property Plant And Equipment (T

Property Plant And Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment	Major classes of property, plant and equipment and their respective balances for the Companies are as follows: At December 31, 2018 2017 (millions) Dominion Energy Utility: Generation $ 19,250 $ 17,602 Transmission 16,669 15,335 Distribution 18,549 17,408 Storage 2,905 2,887 Nuclear fuel 1,626 1,599 Gas gathering and processing 307 219 Oil and gas 1,763 1,720 General and other 1,476 1,514 Plant under construction 2,385 7,765 Total utility 64,930 66,049 Nonutility: Merchant generation-nuclear 1,550 1,452 Merchant generation-other 3,802 4,992 Nuclear fuel 1,025 968 Gas gathering and processing 185 630 LNG facility 3,977 — Other-including plant under construction 1,109 732 Total nonutility 11,648 8,774 Total property, plant and equipment $ 76,578 $ 74,823 Virginia Power Utility: Generation $ 19,250 $ 17,602 Transmission 9,392 8,332 Distribution 11,785 11,151 Nuclear fuel 1,626 1,599 General and other 821 794 Plant under construction 1,639 2,840 Total utility 44,513 42,318 Nonutility-other 11 11 Total property, plant and equipment $ 44,524 $ 42,329 Dominion Energy Gas Utility: Transmission $ 4,758 $ 4,732 Distribution 3,527 3,267 Storage 1,691 1,688 Gas gathering and processing 210 202 General and other 233 216 Plant under construction 494 293 Total utility 10,913 10,398 Nonutility: Gas gathering and processing 185 630 Other-including plant under construction 140 145 Total nonutility 325 775 Total property, plant and equipment $ 11,238 $ 11,173
Schedule of Jointly Owned Utility Plants	Dominion Energy and Virginia Power’s proportionate share of jointly-owned power stations at December 31, 2018 is as follows: Bath (1) North (1) Clover (1) Millstone (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % Plant in service 1,058 2,560 590 1,231 Accumulated depreciation (639 ) (1,305 ) (240 ) (400 ) Nuclear fuel — 721 — 571 Accumulated amortization of nuclear fuel — (608 ) — (423 ) Plant under construction 6 103 9 66 (1) Units jointly owned by Virginia Power. (2) Unit jointly owned by Dominion Energy.
SCANA
Property, Plant and Equipment	At the date of the SCANA Combination, major classes of property, plant and equipment and their respective balances for SCANA are as follows: 2018 (millions) Utility: Generation $ 5,720 Transmission 2,416 Distribution 6,044 Storage 99 Nuclear fuel 611 General and other 631 Plant under construction 527 Total utility 16,048 Nonutility, including plant under construction 283 Total property, plant and equipment $ 16,331
Schedule of Jointly Owned Utility Plants	Actual average composite depreciation rates for SCANA’s utility property, plant and equipment were as follows: 2018 (millions) Generation 2.61 % Transmission 2.47 Distribution 2.48 Storage 2.48 General and other 5.64

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2018
Annual amortization expense of intangible assets	Annual amortization expense for these intangible assets is estimated to be as follows: 2019 2020 2021 2022 2023 (millions) Dominion Energy $ 67 $ 56 $ 44 $ 34 $ 23 Virginia Power $ 29 $ 23 $ 16 $ 12 $ 6 Dominion Energy Gas $ 14 $ 13 $ 12 $ 8 $ 7
Segment allocation of goodwill	The changes in Dominion Energy and Dominion Energy Gas’ carrying amount and segment allocation of goodwill are presented below: Power Generation Gas Infrastructure Power Delivery Corporate and (1) Total (millions) Dominion Energy Balance at December 31, 2016 (2) $ 1,422 $ 4,051 $ 926 $ — $ 6,399 Dominion Energy Questar Combination — 6 (3 ) — — 6 Balance at December 31, 2017 (2) $ 1,422 $ 4,057 $ 926 $ — $ 6,405 Purchase Accounting Adjustment — 5 — — 5 Balance at December 31, 2018 (2) $ 1,422 $ 4,062 $ 926 $ — $ 6,410 Dominion Energy Gas Balance at December 31, 2016 (2) $ — $ 542 $ — $ — $ 542 No events affecting goodwill — — — — — Balance at December 31, 2017 (2) $ — $ 542 $ — $ — $ 542 Purchase Accounting Adjustment — 5 — — 5 Balance at December 31, 2018 (2) $ — $ 547 $ — $ — $ 547 (1) Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes. (2) Goodwill amounts do not contain any accumulated impairment losses. (3) See Note 3.
Components of intangible assets	years. The components of intangible assets are as follows: 2018 2017 At December 31, Gross Accumulated Gross Accumulated (millions) Dominion Energy Software, licenses and other $ 1,033 $ 363 $ 1,043 $ 358 Virginia Power Software, licenses and other $ 384 $ 134 $ 347 $ 114 Dominion Energy Gas Software, licenses and other $ 174 $ 65 $ 165 $ 56
SCANA
Annual amortization expense of intangible assets	Annual amortization expense for these intangible assets is estimated to be as follows: 2019 2020 2021 2022 2023 (millions) SCANA $ 95 $ 90 $ 80 $ 74 $ 71

Short-Term Debt And Credit Ag_2

Short-Term Debt And Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2018
Schedule of Line of Credit Facilities	Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities were as follows: Facility Outstanding (1) Outstanding Facility (millions) At December 31, 2018 Joint revolving credit facility (2) $ 6,000 $ 324 $88 $ 5,588 At December 31, 2017 Joint revolving credit facility (3) $ 5,000 $3,298 $— $ 1,702 Joint revolving credit facility (3) 500 — 76 424 Total $ 5,500 $3,298 $76 $ 2,126 (1) The weighted-average interest rates of the outstanding commercial paper supported by Dominion Energy’s credit facilities were 2.93% and 1.61% at December 31, 2018 and 2017, respectively. (2) This credit facility matures in March 2023 and can be used by the Companies 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. (3) These credit facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The facilities were scheduled to mature in April 2020 and were 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.
Virginia Electric and Power Company
Schedule of Line of Credit Facilities	Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion Energy, Dominion Energy Gas and Questar Gas were as follows: Facility Outstanding (1) Outstanding (millions) At December 31, 2018 Joint revolving credit facility (2) $6,000 $314 $16 At December 31, 2017 Joint revolving credit facility (3) $5,000 $542 $— Joint revolving credit facility (3) 500 — — Total $5,500 $542 $— (1) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.94% and 1.65% at December 31, 2018 and 2017, respectively. (2) The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers sub-limit sub-limit sub-limit, sub-limit sub-limit, (3) These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The full amount of the facilities was available to Virginia Power, less any amounts outstanding to co-borrowers sub-limit,
Dominion Energy Gas Holdings, LLC
Schedule of Line of Credit Facilities	Dominion Energy Gas’ share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion Energy, Virginia Power and Questar Gas were as follows: Facility Outstanding (1) Outstanding (millions) At December 31, 2018 Joint revolving credit facility (2) $1,500 $ 10 $— At December 31, 2017 Joint revolving credit facility (3) $1,000 $629 $— Joint revolving credit facility (3) 500 — — Total $1,500 $629 $— (1) The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.58% and 1.57% at December 31, 2018 and 2017, respectively. (2) A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers sub-limit sub-limit sub-limit, sub-limit sub-limit, (3) These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. A maximum of a combined $1.5 billion of the facilities was available to Dominion Energy Gas, assuming adequate capacity was available after giving effect to uses by co-borrowers sub-limit,
SCANA
Schedule of Line of Credit Facilities	At closing of the SCANA Combination, commercial paper and letters of credit outstanding, as well as capacity available under SCANA’s existing credit facilities were as follows: SCANA Corporation SCE&G PSNC Total (millions, except percentages) Total facility limit $ 400 $ 1,200 (1) $ 200 $ 1,800 Letters of credit advances 40 (2) — — 40 Weighted-average interest rate 3.87 % n/a n/a 3.87 % Outstanding commercial paper 2 73 98 173 Weighted-average interest rate 3.65 % 3.82 % 3.49 % 3.63 % Outstanding letters of credit 37 — — 37 Facility capacity available $ 321 $ 1,127 $ 102 $ 1,550 (1) Includes South Carolina Fuel Company, Inc.’s $500 million credit facility. (2) In January 2019, SCANA repaid $40 million in letter of credit advances.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Long term Debt	At December 31, 2018 Weighted- average Coupon (1) 2018 2017 (millions, except percentages) Dominion Energy Gas Holdings, LLC: Unsecured Senior Notes: Variable rate, due 2021 3.39 % $ 500 $ — 2.5% to 3.55%, due 2019 to 2023 2.90 % 1,800 1,800 3.317% to 4.8%, due 2024 to 2044 (2) 4.12 % 1,787 1,800 Dominion Energy Gas Holdings, LLC total principal $ 4,087 $ 3,600 Securities due within one year 2.50 % (449 ) — Unamortized discount and debt issuance costs (29 ) (30 ) Dominion Energy Gas Holdings, LLC total long-term debt $ 3,609 $ 3,570 Virginia Electric and Power Company: Unsecured Senior Notes: 1.2% to 5.4%, due 2018 to 2023 3.35 % $ 1,800 $ 2,650 2.95% to 8.875%, due 2024 to 2048 4.61 % 9,290 7,990 Tax-Exempt (3) Variable rates, due 2024 to 2027 — 100 1.75% to 5.6%, due 2023 to 2041 2.18 % 664 678 Virginia Electric and Power Company total principal $ 11,754 $ 11,418 Securities due within one year 5.00 % (350 ) (850 ) Unamortized discount, premium and debt issuances costs, net (83 ) (72 ) Virginia Electric and Power Company total long-term debt $ 11,321 $ 10,496 Dominion Energy, Inc.: Unsecured Senior Notes (4) Variable rates, due 2019 and 2020 3.23 % $ 800 $ 800 1.5% to 6.4%, due 2018 to 2022 2.75 % 2,550 5,800 2.85% to 7.0%, due 2024 to 2044 4.81 % 4,849 5,049 Unsecured Junior Subordinated Notes: 2.579% to 4.104%, due 2019 to 2021 3.08 % 2,100 2,100 Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.25% and 5.75%, due 2054 and 2076 5.48 % 1,485 1,485 Variable rates, due 2066 5.26 % 422 422 Remarketable Subordinated Notes, 2.0%, due 2021 and 2024 2.00 % 1,400 1,400 Unsecured Debentures and Senior Notes (5) 6.8% and 6.875%, due 2026 and 2027 6.81 % 89 89 Unsecured Senior and Medium-Term Notes (6) 5.31% and 6.3%, due 2018 — 120 2.98% to 7.20%, due 2024 to 2051 4.25 % 750 600 Secured Senior Notes, 4.82%, due 2042 (7) 4.82 % 362 — Term Loans, variable rates, due 2023 and 2024 (8) 4.85 % 582 638 Tax-Exempt (9) 1.55 % 27 27 Capital leases, 4.14% to 6.04%, due 2019 to 2029 5.99 % 39 — Dominion Energy Midstream Partners, LP: Term Loans, variable rates, due 2019 and 2021 (10)(11) 4.13 % 3,300 300 Revolving Credit Agreement, variable rates, due 2021 (11) 3.55 % 73 — Unsecured Senior and Medium-Term Notes, 5.83% and 6.48%, due 2018 (12) — 255 Unsecured Senior Notes, 3.53% to 4.875%, due 2028 to 2041 (12) 4.23 % 430 180 Dominion Energy Gas Holdings, LLC total principal (from above) 4,087 3,600 Virginia Electric and Power Company total principal (from above) 11,754 11,418 Dominion Energy, Inc. total principal $ 35,109 $ 34,293 Fair value hedge valuation (13) (20 ) (22 ) Securities due within one year (14)(15) 3.23 % (3,624 ) (3,078 ) Credit facility borrowings (11) 3.55 % (73 ) — Unamortized discount, premium and debt issuance costs, net (248 ) (245 ) Dominion Energy, Inc. total long-term debt $ 31,144 $ 30,948 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2018. (2) Amount includes foreign currency remeasurement adjustments. (3) These financings relate to certain pollution control equipment at Virginia Power’s generating facilities. In March 2018, Virginia Power redeemed certain variable rate tax-exempt (4) In November and December 2018, Dominion Energy redeemed certain senior notes prior to their stated maturity. See below for a discussion of the senior note redemptions. (5) Represents debt assumed by Dominion Energy from the merger of its former CNG subsidiary. (6) Represents debt obligations of Questar Gas. See Note 3 for more information. (7) Represents debt obligations of Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain merchant solar facilities. (8) Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt is nonrecourse to Dominion Energy and is secured by SBL Holdco and Dominion Solar Projects III, Inc.’s interest in certain merchant solar facilities. (9) Represents debt obligations of a DGI subsidiary. (10) Includes debt obligations of Cove Point that are secured by Dominion Energy’s common equity interest in Cove Point. (11) In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy’s Consolidated Balance Sheets at December 31, 2018. (12) Represents debt obligations of Dominion Energy Questar Pipeline. See Note 3 for more information. (13) Represents the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt. (14) 2017 excludes $250 million of Dominion Energy Questar Pipeline’s senior notes that matured in February 2018 using proceeds from the January 2018 issuance, through private placements, of $100 million and $150 million of senior notes that mature in 2028 and 2038, respectively. (15) Includes $20 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc.
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, 2018, were as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions, except percentages) Dominion Energy Gas $ 450 $ 700 $ 500 $ — $ 650 $ 1,787 $ 4,087 Weighted-average Coupon 2.50 % 2.80 % 3.39 % 3.29 % 4.12 % Virginia Power Unsecured Senior Notes $ 350 $ — $ — $ 750 $ 700 $ 9,290 $ 11,090 Tax-Exempt — — — — 40 624 664 Total $ 350 $ — $ — $ 750 $ 740 $ 9,914 $ 11,754 Weighted-average Coupon 5.00 % 3.15 % 2.87 % 4.45 % Dominion Energy Term Loans (1)(2) $ 336 $ 35 $ 3,035 $ 34 $ 273 $ 169 $ 3,882 Credit Facility Borrowings (2) — — 73 — — — 73 Unsecured Senior Notes 2,700 1,000 900 1,500 1,350 17,195 24,645 Secured Senior Notes 17 15 17 19 16 278 362 Tax-Exempt — — — — 40 651 691 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Unsecured Junior Subordinated Notes 550 1,000 550 — — — 2,100 Enhanced Junior Subordinated Notes — — — — — 1,907 1,907 Remarketable Subordinated Notes — — 700 — — 700 1,400 Capital leases 4 4 4 3 3 21 39 Total $ 3,607 $ 2,054 $ 5,279 $ 1,556 $ 1,682 $ 20,931 $ 35,109 Weighted-average Coupon 3.23 % 2.80 % 3.64 % 3.02 % 3.41 % 4.51 % (1) Excludes mandatory prepayments associated with SBL Holdco and Dominion Solar Projects III, Inc. based on cash flows in excess of debt service. At December 31, 2018, $20 million of estimated mandatory prepayments due within one year were included in securities due within one year in Dominion Energy’s Consolidated Balance Sheets. (2) In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy’s Consolidated Balance Sheets at December 31, 2018.
Schedule of Capital Units	Selected information about Dominion Energy’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 (millions, except interest rates) 8/15/2016 (2) 28 $ 1,374.8 $1,400.0 2.000 % (3) 4.750 % $190.6 8/15/2019 (1) Payments of $64 million and $101 million were made in 2018 and 2017, respectively, including payments for the remarketed 2014 Series A notes. The stock purchase contract liability was $47 million and $111 million at December 31, 2018 and 2017, respectively. (2) The maturity dates of the $700 million Series A-1 A-2 (3) Annual interest rate applies to each of the Series A-1 A-2
SCANA
Long term Debt	At closing of the SCANA Combination, SCANA had the following long-term debt outstanding which is part of the total consideration provided for the transaction. Weighted- average Coupon (1) Amount (millions, except percentages) Unsecured medium term notes, due 2020 to 2022 5.42 % $ 800 Unsecured senior notes, due 2019 to 2034 3.44 70 First mortgage bonds, due 2021 to 2065 5.52 4,990 GENCO notes, due 2019 to 2024 5.49 40 Industrial and pollution control bonds, due 2028 to 2038 (2) 3.52 122 PSNC senior debentures and notes, due 2020 to 2047 5.07 700 Other, due 2019 to 2027 3.46 73 Total principal $ 6,795 Current maturities of long-term debt (59 ) Unamortized discount, premium and debt issuance costs, net (29 ) SCANA total long-term debt $ 6,707 (1) Represents weighted-average coupon rates for debt outstanding at closing of the SCANA Combination. (2) Includes variable rate debt of $68 million, with a weighted-average interest rate of 1.72%, which is hedged by fixed swaps.
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 closing of the SCANA Combination, were as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions, except Unsecured senior notes $ 4 $ 4 $ 4 $ 4 $ 4 $ 50 $ 70 Unsecured medium term notes — 250 300 250 — — 800 First mortgage bonds — — 330 — — 4,660 4,990 PSNC senior debentures and notes — 100 150 — — 450 700 GENCO notes 7 7 7 7 7 5 40 Industrial and pollution control bonds — — — — — 122 122 Other 48 7 6 5 3 4 73 Total $ 59 $ 368 $ 797 $ 266 $ 14 $ 5,291 $ 6,795 Weighted-average coupon 3.91 % 6.26 % 4.20 % 5.22 % 3.29 % 5.51 % 5.36 %

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2018
Lease Commitments	Future minimum lease payments under noncancelable operating leases that have initial or remaining lease terms in excess of one year as of December 31, 2018 are as follows: 2019 2020 2021 2022 2023 Thereafter Total (millions) Dominion Energy $ 64 $ 61 $ 55 $ 47 $ 38 $ 384 $ 649 Virginia Power 34 32 28 22 16 106 238 Dominion Energy Gas 12 11 9 7 4 3 46
Nuclear Insurance	The current levels of nuclear property insurance coverage for Dominion Energy and Virginia Power’s nuclear units are as follows: Coverage (billions) Dominion Energy Millstone $ 1.70 Kewaunee 0.05 Virginia Power (1) Surry $ 1.70 North Anna 1.70 (1) Surry and North Anna share a blanket property limit of $200 million.
Schedule Of Subsidiary Guarantees	At December 31, 2018, Dominion Energy had issued the following subsidiary guarantees: Maximum Exposure (millions) Commodity transactions (1) $ 2,186 Nuclear obligations (2) 179 Cove Point (3) 1,900 Solar (4) 659 Other (5) 420 Total (6) $ 5,344 (1) Guarantees related to commodity commitments of certain subsidiaries. These guarantees were provided to counterparties in order to facilitate physical and financial transaction related commodities and services. (2) Guarantees related to certain DGI subsidiaries’ regarding all aspects of running a nuclear facility. (3) Guarantees related to Cove Point, in support of terminal services, transportation and construction. Cove Point has two guarantees that have no maximum limit and, therefore, are not included in this amount. (4) Includes guarantees to facilitate the development of solar projects. Also includes guarantees entered into by DGI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects. (5) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Due to the uncertainty of worker’s compensation claims, the parental guarantee has no stated limit. Also included are guarantees related to certain DGI subsidiaries’ obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of December 31, 2018, Dominion Energy’s maximum remaining cumulative exposure under these equity funding agreements is $4 million through 2019 and its maximum annual future contribution is approximately $4 million. (6) Excludes Dominion Energy’s guarantee for the construction of the new corporate office property discussed further within Lease Commitments above.
Virginia Electric and Power Company
Long-term Purchase Commitment	At December 31, 2018, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that a third party has used to secure financing for the facility that will provide the contracted goods or services: 2019 2020 2021 2022 2023 Thereafter Total (millions) Purchased electric capacity (1) $ 60 $ 52 $ 46 $ — $ — $ — $ 158 (1) Commitments represent estimated amounts payable for capacity under power purchase contracts with independent power producers, which end 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, 2018, the present value of Virginia Power’s total commitment for capacity payments is $142 million. Capacity payments totaled $50 million, $114 million and $248 million, and energy payments totaled $42 million, $72 million and $126 million for the years ended 2018, 2017 and 2016, respectively.
SCANA
Long-term Purchase Commitment	SCANA has the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that a third party has used to secure financing for the facility that will provide the contracted goods or services: 2019 2020 2021 2022 2023 Thereafter Total (millions) Purchased electric capacity (1) $ 31 $ 30 $ 30 $ 30 $ 30 $ 310 $ 461 (1) Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities which expire at various dates through 2046. Capacity payments under the contracts are generally based on fixed dollar amounts per month.
Lease Commitments	SCANA is obligated under various operating leases for land, office space, furniture, equipment, rail cars and airplanes. Such leases expire at various dates through 2057. 2019 2020 2021 2022 2023 Thereafter Total (millions) Operating leases $ 10 $ 8 $ 7 $ 6 $ 4 $ 30 $ 65

Operating Revenue (Tables)

Operating Revenue (Tables)	12 Months Ended
	Dec. 31, 2018
Operating Revenue For Revised Guidance of Revenue Recognition From Contracts with Customers	The Companies’ operating revenue, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, consists of the following: Year Ended December 31, 2018 (millions) Dominion Energy Regulated electric sales: Residential $ 3,413 Commercial 2,503 Industrial 490 Government and other retail 854 Wholesale 137 Nonregulated electric sales 1,294 Regulated gas sales: Residential 818 Commercial 221 Other 36 Nonregulated gas sales 214 Regulated gas transportation and storage: FERC-regulated 1,091 State-regulated 640 Nonregulated gas transportation and storage 442 Other regulated revenues 179 Other nonregulated revenues (1)(2) 563 Total operating revenue from contracts with customers 12,895 Other revenues (2) (3) 471 Total operating revenue $ 13,366 Virginia Power Regulated electric sales: Residential $ 3,413 Commercial 2,503 Industrial 490 Government and other retail 854 Wholesale 137 Other regulated revenues 132 Other nonregulated revenues (1)(2) 55 Total operating revenue from contracts with customers 7,584 Other revenues (1 ) (3) 35 Total operating revenue $ 7,619 Dominion Energy Gas Regulated gas sales: Residential $ 81 Other 27 Nonregulated gas sales (1) 13 Regulated gas transportation and storage: FERC-regulated (1) 763 State-regulated (1) 605 NGL revenue (1)(2) 223 Management service revenue (1) 205 Other regulated revenues (1) 22 Other nonregulated revenues (1) 10 Total operating revenue from contracts with customers 1,949 Other revenues (9 ) Total operating revenue $ 1,940 (1) See Notes 9 and 24 for amounts attributable to related parties and affiliates. (2) Amounts above include $241 million and $206 million for the year ended December 31, 2018 primarily consisting of NGL sales at Dominion Energy and Dominion Energy Gas, respectively, which are considered to be goods transferred at a point in time. In addition, the amounts include $17 million and $11 million of sales of renewable energy credits at both Dominion Energy and Virginia Power for the year ended December 31, 2018, respectively, which are considered to be goods transferred at a point in time. (3) Amounts above include $15 million of alternative revenue at Dominion Energy and Virginia Power for the year ended December 31, 2018.
Schedule of Aggregate Amount of Transaction Price Allocated To Fixed-price Performance Obligations That Unsatisfied At End of Reporting Period And Expected To be Recognized	The table below discloses the aggregate amount of the transaction price allocated to fixed-price performance obligations that are unsatisfied (or partially unsatisfied) at the end of the reporting period and when the Companies expect to recognize this revenue. These revenues relate to contracts containing fixed prices where the Companies will earn the associated revenue over time as they stand ready to perform services provided. This disclosure does not include revenue related to performance obligations that are part of a contract with original durations of one year or less. In addition, this disclosure does not include expected consideration related to performance obligations for which the Companies elect to recognize revenue in the amount they have a right to invoice. Revenue expected to be recognized on multi-year contracts in place at December 31, 2018 2019 2020 2021 2022 2023 Thereafter Total (millions) Dominion Energy $ 1,643 $ 1,563 $ 1,448 $ 1,319 $ 1,154 $ 13,693 $ 20,820 Virginia Power 21 3 1 — — — 25 Dominion Energy Gas 600 560 475 384 268 1,612 3,899
Subsequent To Adoption of Revised Guidance
Operating Revenue For Revised Guidance of Revenue Recognition From Contracts with Customers	The Companies’ operating revenue, prior to the adoption of revised guidance for revenue recognition from contracts with customers, consisted of the following: Year Ended December 31, 2017 2016 (millions) Dominion Energy Electric sales: Regulated $ 7,383 $ 7,348 Nonregulated 1,429 1,519 Gas sales: Regulated 1,067 500 Nonregulated 457 354 Gas transportation and storage 1,786 1,636 Other 464 380 Total operating revenue $ 12,586 $ 11,737 Virginia Power Regulated electric sales $ 7,383 $ 7,348 Other 173 240 Total operating revenue $ 7,556 $ 7,588 Dominion Energy Gas Gas sales: Regulated $ 87 $ 119 Nonregulated 20 13 Gas transportation and storage 1,435 1,307 NGL revenue 91 62 Other 181 137 Total operating revenue $ 1,814 $ 1,638

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
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 Energy Virginia Power Dominion Energy Gas Year Ended December 31, 2018 2017 2016 2018 2017 2016 2018 2017 2016 (millions) Current: Federal $ (45 ) $ (1 ) $ (155 ) $ 36 $ 432 $ 168 $ 23 $ 16 $ (27 ) State 108 (26 ) 85 40 73 90 30 8 4 Total current expense (benefit) 63 (27 ) (70 ) 76 505 258 53 24 (23 ) Deferred: Federal 2017 Tax Reform Act impact 46 (851 ) — 21 (93 ) — (11 ) (197 ) — Taxes before operating loss carryforwards and investment tax credits 436 739 1,050 199 319 435 48 199 239 Tax utilization expense (benefit) of operating loss carryforwards 92 174 (161 ) — 4 (2 ) — 5 (2 ) Investment tax credits (56 ) (200 ) (248 ) (51 ) (23 ) (25 ) — — — State (1 ) 132 50 55 59 27 (4 ) 20 1 Total deferred expense (benefit) 517 (6 ) 691 224 266 435 33 27 238 Investment tax credit-gross deferral 2 5 35 2 5 35 — — — Investment tax credit-amortization (2 ) (2 ) (1 ) (2 ) (2 ) (1 ) — — — Total income tax expense (benefit) $ 580 $ (30 ) $ 655 $ 300 $ 774 $ 727 $ 86 $ 51 $ 215
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 Energy Virginia Power Dominion Energy Gas Year Ended December 31, 2018 2017 2016 2018 2017 2016 2018 2017 2016 U.S. statutory rate 21.0 % 35.0 % 35.0 % 21.0 % 35.0 % 35.0 % 21.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.0 2.0 2.4 4.7 3.7 3.8 3.2 2.4 0.5 Investment tax credits (1.9 ) (6.3 ) (11.7 ) (3.5 ) (0.8 ) — — — — Production tax credits (0.7 ) (0.7 ) (0.8 ) (0.7 ) (0.4 ) (0.5 ) — — — Valuation allowances 0.3 0.2 1.2 — — 0.1 1.8 0.3 — Reversal of excess deferred income taxes (2.0 ) — — (3.2 ) — — (1.7 ) — — Federal legislative change 1.5 (27.5 ) — 1.3 (4.0 ) — (2.8 ) (29.5 ) — State legislative change (0.6 ) — (0.6 ) — — — 0.2 — — AFUDC—equity (0.8 ) (1.4 ) (0.6 ) (0.5 ) (0.6 ) (0.6 ) (0.6 ) (0.9 ) (0.2 ) Employee stock ownership plan deduction (0.4 ) (0.6 ) (0.6 ) — — — — — — Other, net (0.9 ) (1.7 ) (1.4 ) (0.1 ) 0.6 (0.4 ) 1.2 0.4 0.1 Effective tax rate 18.5 % (1.0 )% 22.9 % 19.0 % 33.5 % 37.4 % 22.3 % 7.7 % 35.4 %
Deferred income taxes components	The Companies’ deferred income taxes consist of the following: Dominion Energy Virginia Power Dominion Energy At December 31, 2018 2017 2018 2017 2018 2017 (millions) Deferred income taxes: Total deferred income tax assets $ 2,748 $ 2,686 $ 1,054 $ 923 $ 318 $ 320 Total deferred income tax liabilities 7,813 7,158 4,020 3,600 1,783 1,774 Total net deferred income tax liabilities $ 5,065 $ 4,472 $ 2,966 $2,677 $1,465 $ 1,454 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 4,933 $ 5,056 $ 3,367 $2,969 $1,170 $ 1,132 Excess deferred income taxes (993 ) (1,050 ) (678 ) (687 ) (254 ) (244 ) Nuclear decommissioning 815 829 273 260 — — Deferred state income taxes 626 834 284 378 175 227 Federal benefit of deferred state income taxes (132 ) (175 ) (60 ) (79 ) (37 ) (48 ) Deferred fuel, purchased energy and gas costs 60 1 59 (3 ) 1 2 Pension benefits 81 141 (132 ) (104 ) 431 419 Other postretirement benefits (5 ) (51 ) 55 44 (1 ) (2 ) Loss and credit carryforwards (1,546 ) (1,536 ) (183 ) (111 ) (7 ) (4 ) Valuation allowances 158 146 5 5 12 3 Partnership basis differences 1,135 473 — — 26 26 Other (67 ) (196 ) (24 ) 5 (51 ) (57 ) Total net deferred income tax liabilities $ 5,065 $ 4,472 $ 2,966 $2,677 $1,465 $ 1,454 Deferred Investment Tax Credits – Regulated Operations 51 51 51 51 — — Total Deferred Taxes and Deferred Investment Tax Credits $ 5,116 $ 4,523 $ 3,017 $2,728 $1,465 $ 1,454
Summary of deductible loss and credit carryforwards	At December 31, 2018, Dominion Energy had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Federal losses $ 120 $ 25 $ — 2034 Federal investment credits — 1,007 — 2033-2038 Federal production credits — 150 — 2031-2038 Other federal credits — 62 — 2031-2038 State losses 1,126 73 (61 ) 2019-2038 State minimum tax credits — 122 — No expiration State investment and other credits — 107 (90 ) 2019-2025 Total $1,246 $ 1,546 $(151) At December 31, 2018, Virginia Power had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Federal losses $ 1 $ — $ — 2034 Federal investment credits — 113 — 2034-2038 Federal production and other credits — 61 — 2031-2038 State investment credits — 9 (5 ) 2024 Total $ 1 $183 $(5 ) At December 31, 2018, Dominion Energy Gas had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration (millions) Other federal credits $ — $ 1 $ — 2032-2037 State losses 53 5 (5 ) 2036-2038 Total $ 53 $ 6 $ (5 )
Reconciliation of changes in unrecognized tax benefits	A reconciliation of changes in the Companies’ unrecognized tax benefits follows: Dominion Energy Virginia Power Dominion Energy Gas 2018 2017 2016 2018 2017 2016 2018 2017 2016 (millions) Balance at January 1 $ 38 $ 64 $ 103 $ 4 $ 13 $ 12 $ — $ 7 $29 Increases-prior period positions 10 1 9 — — 4 — — 1 Decreases-prior period positions — (9 ) (44 ) — (1 ) (3 ) — — (19 ) Increases-current period positions 10 5 6 — — — — — — Settlements with tax authorities (6 ) (23 ) (8 ) (1 ) (8 ) — — (7 ) (4 ) Expiration of statutes of limitations (8 ) — (2 ) (1 ) — — — — — Balance at December 31 $ 44 $ 38 $ 64 $ 2 $ 4 $ 13 $— $ — $ 7

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
Fair Value Inputs, Assets, Quantitative Information	The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at December 31, 2018. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility. Fair Value (millions) Valuation Techniques Unobservable Input Range Weighted (1) Assets Physical and financial forwards and futures: Natural gas (2) $42 Discounted cash flow Market price (per Dth) (3) (2) - 8 (1 ) FTRs 15 Discounted cash flow Market price (per MWh) (3) (2) - 7 1 Physical options: Natural gas 2 Option model Market price (per Dth) (3) 1 - 8 3 Price volatility (4) 18% - 73% 30 % Electricity 11 Option model Market price (per MWh) (3) 34 - 50 42 Price volatility (4) 39% - 60% 49 % Total assets $70 Liabilities Financial forwards: FTRs $ 6 Discounted cash flow Market price (per MWh) (3) (2) - 6 — Total liabilities $ 6 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents volatilities unrepresented in published markets.
Fair Value, Option, Qualitative Disclosures	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 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)
Fair Value, by Balance Sheet Grouping	The following table presents Dominion Energy’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) December 31, 2018 Assets Derivatives: Commodity $ — $ 180 $ 70 $ 250 Interest rate — 18 — 18 Foreign currency — 26 — 26 Investments (1) Equity securities: U.S. 3,277 — — 3,277 Fixed income: Corporate debt instruments — 431 — 431 Government securities 455 688 — 1,143 Cash equivalents and other 11 — — 11 Total assets $ 3,743 $ 1,343 $ 70 $ 5,156 Liabilities Derivatives: Commodity $ — $ 129 $ 6 $ 135 Interest rate — 142 — 142 Foreign currency — 2 — 2 Total liabilities $ — $ 273 $ 6 $ 279 December 31, 2017 Assets Derivatives: Commodity $ — $ 101 $157 $ 258 Interest rate — 17 — 17 Foreign currency — 32 — 32 Investments (1) Equity securities: U.S. 3,493 — — 3,493 Fixed income: Corporate debt instruments — 444 — 444 Government securities 307 794 — 1,101 Cash equivalents and other 34 — — 34 Total assets $ 3,834 $ 1,388 $157 $ 5,379 Liabilities Derivatives: Commodity $ — $ 190 $ 7 $ 197 Interest rate — 85 — 85 Foreign currency — 2 — 2 Total liabilities $ — $ 277 $ 7 $ 284 (1) Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $220 million and $88 million of assets at December 31, 2018 and 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	The following table presents the net change in Dominion Energy’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category: 2018 2017 2016 (millions) Balance at January 1, $ 150 $ 139 $ 95 Total realized and unrealized gains (losses): Included in earnings: Operating Revenue (2 ) 3 — Electric fuel and other energy-related purchases (15 ) (42 ) (35 ) Purchased gas — 1 — Included in other comprehensive income (loss) 1 (2 ) — Included in regulatory assets/liabilities (44 ) 42 (39 ) Settlements (27 ) 6 38 Purchases — — 87 Transfers out of Level 3 1 3 (7 ) Balance at December 31, $ 64 $ 150 $ 139 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: Operating Revenue $ — $ 2 $ — Electric fuel and other energy-related purchases — — (1 )
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	instruments. For the Companies’ financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows: December 31, 2018 2017 Carrying Amount Estimated (1) Carrying Amount Estimated (1) (millions) Dominion Energy Long-term debt, including securities due within one year (2) $ 29,952 $31,045 $ 28,666 $31,233 Credit facility borrowings 73 73 — — Junior subordinated notes (3) 3,430 3,358 3,981 4,102 Remarketable subordinated notes (3) 1,386 1,340 1,379 1,446 Virginia Power Long-term debt, including securities due within one year (3) $ 11,671 $12,400 $ 11,346 $12,842 Dominion Energy Gas Long-term debt, including securities due within one year (4) $ 4,058 $ 4,072 $ 3,570 $ 3,719 (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 issuances 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 debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At December 31, 2018, and 2017, includes the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt of $(20) million and $(22) million, respectively. (3) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium. (4) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments.
Virginia Electric and Power Company
Fair Value Inputs, Assets, Quantitative Information	The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at December 31, 2018. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility. Fair Value Valuation Techniques Unobservable Input Range Weighted (1) Assets Physical and financial forwards and futures: Natural gas (2) $38 Discounted cash flow Market price (per Dth) (3) (2)-8 (1 ) FTRs 15 Discounted cash flow Market price (per MWh) (3) (2)-7 1 Physical options: Natural gas 2 Option model Market price (per Dth) (3) 1-8 3 Price volatility (4) 18%-73% 30 % Electricity 11 Option model Market price (per MWh) (3) 34-50 42 Price volatility (4) 39%-60% 49 % Total assets $66 Liabilities Financial forwards: FTRs $ 6 Discounted cash flow Market price (per MWh) (3) (2)-6 — Total liabilities $ 6 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents volatilities unrepresented in published markets.
Fair Value, Option, Qualitative Disclosures	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 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)
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) December 31, 2018 Assets Derivatives: Commodity $ — $ 24 $ 66 $ 90 Interest rate — 3 — 3 Investments (1) Equity securities: U.S. 1,476 — — 1,476 Fixed income: Corporate debt instruments — 221 — 221 Government securities 164 343 — 507 Total assets $ 1,640 $ 591 $ 66 $ 2,297 Liabilities Derivatives: Commodity $ — $ 9 $ 6 $ 15 Interest rate — 88 — 88 Total liabilities $ — $ 97 $ 6 $ 103 December 31, 2017 Assets Derivatives: Commodity $ — $ 14 $ 152 $ 166 Investments (1) Equity securities: U.S. 1,566 — — 1,566 Fixed income: Corporate debt instruments — 224 — 224 Government securities 168 326 — 494 Cash equivalents and other 16 — — 16 Total assets $ 1,750 $ 564 $ 152 $ 2,466 Liabilities Derivatives: Commodity $ — $ 4 $ 5 $ 9 Interest rate — 57 — 57 Total liabilities $ — $ 61 $ 5 $ 66 (1) Includes investments held in the nuclear decommissioning trusts. Excludes $160 million and $27 million of assets at December 31, 2018 and 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.
Fair Value, Net Derivative Asset (Liability) 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: 2018 2017 2016 (millions) Balance at January 1, $ 147 $ 143 $ 93 Total realized and unrealized gains (losses): Included in earnings: Electric fuel and other energy-related purchases (17 ) (43 ) (35 ) Included in regulatory assets/liabilities (45 ) 40 (37 ) Settlements (25 ) 7 35 Purchases — — 87 Balance at December 31, $ 60 $ 147 $ 143
Dominion Energy Gas Holdings, LLC
Fair Value, by Balance Sheet Grouping	The following table presents Dominion Energy Gas’ assets and liabilities for 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) December 31, 2018 Assets Commodity $ — $ 3 $ — $ 3 Foreign currency — 26 — 26 Total assets $ — $29 $ — $29 Liabilities Interest rate $ — $17 $ — $17 Foreign currency — 2 — 2 Total liabilities $ — $19 $ — $19 December 31, 2017 Assets Foreign currency $ — $32 $ — $32 Total assets $ — $32 $ — $32 Liabilities Commodity $ — $ 4 $ 2 $ 6 Foreign currency — 2 — 2 Total liabilities $ — $ 6 $ 2 $ 8
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	The following table presents the net change in Dominion Energy Gas’ derivative assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category: 2018 2017 2016 (millions) Balance at January 1, $ (2 ) $ (2 ) $ 6 Total realized and unrealized gains (losses): Included in other comprehensive income (loss) 1 (3 ) — Transfers out of Level 3 1 3 (8 ) Balance at December 31, $ — $ (2 ) $ (2 )

Derivatives And Hedge Account_2

Derivatives And Hedge Accounting Activities (Tables)	12 Months Ended
	Dec. 31, 2018
Offsetting Assets	The tables below present Dominion Energy’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset Gross Amounts Not Offset Gross Assets (1) Financial Cash Net Gross Assets (1) Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 175 $ 12 $ — $ 163 $ 174 $ 9 $ — $ 165 Exchange 68 68 — — 80 80 — — Interest rate contracts: Over-the-counter 18 1 — 17 17 8 — 9 Foreign currency contracts: Over-the-counter 26 2 — 24 32 2 — 30 Total derivatives, subject to a master netting or similar arrangement $ 287 $ 83 $ — $ 204 $ 303 $ 99 $ — $ 204 (1) Excludes $7 million and $4 million of derivative assets at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements.
Offsetting Liabilities	December 31, 2018 December 31, 2017 Gross Amounts Not Balance Sheet Gross Amounts Not Balance Sheet Gross Liabilities (1) Financial Cash Net Gross Liabilities (1) Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 19 $ 12 $ — $ 7 $ 76 $ 9 $ 6 $ 61 Exchange 115 68 47 — 120 80 40 — Interest rate contracts: Over-the-counter 142 1 — 141 85 8 — 77 Foreign currency contracts: Over-the-counter 2 2 — — 2 2 — — Total derivatives, subject to a master netting or similar arrangement $ 278 $ 83 $ 47 $ 148 $ 283 $ 99 $ 46 $ 138 (1) Excludes $1 million of derivative liabilities at December 31, 2018 and 2017, which are not subject to master netting or similar arrangements.
Schedule of Volume of Derivative Activity	The following table presents the volume of Dominion Energy’s derivative activity as of December 31, 2018. 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) 56 27 Basis 214 557 Electricity (MWh): Fixed price (1) 11,101,869 1,537,200 FTRs 45,351,415 — Liquids (Gal) (2) 14,413,200 — Interest rate (3) $ 2,700,000,000 $ 3,915,839,913 Foreign currency (3)(4) $ — $ 280,000,000 (1) Includes options. (2) Includes NGLs and oil. (3) Maturity is determined based on final settlement period. (4) Euro equivalent volumes are € 250,000,000.
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy’s Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected to be After-Tax Maximum Term (millions) Commodities: Gas $ — $ 1 36 months Electricity 27 26 24 months Other 2 2 3 months Interest rate (276 ) (29 ) 396 months Foreign currency 12 (2 ) 90 months Total $(235 ) $ (2 )
Fair Value of Derivatives	Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – under Fair Value – not under Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ 55 $154 $ 209 Interest rate 14 — 14 Total current derivative assets (1) 69 154 223 Noncurrent Assets Commodity 6 35 41 Interest rate 4 — 4 Foreign currency 26 — 26 Total noncurrent derivative assets (2) 36 35 71 Total derivative assets $105 $189 $ 294 LIABILITIES Current Liabilities Commodity $ 17 $112 $ 129 Interest rate 26 — 26 Foreign currency 2 — 2 Total current derivative liabilities (3) 45 112 157 Noncurrent Liabilities Commodity 5 1 6 Interest rate 116 — 116 Total noncurrent derivative liabilities (4) 121 1 122 Total derivative liabilities $166 $113 $ 279 At December 31, 2017 ASSETS Current Assets Commodity $ 5 $158 $ 163 Interest rate 6 — 6 Total current derivative assets (1) 11 158 169 Noncurrent Assets Commodity — 95 95 Interest rate 11 — 11 Foreign currency 32 — 32 Total noncurrent derivative assets (2) 43 95 138 Total derivative assets $ 54 $253 $ 307 LIABILITIES Current Liabilities Commodity $103 $ 92 $ 195 Interest rate 53 — 53 Foreign currency 2 — 2 Total current derivative liabilities (3) 158 92 250 Noncurrent Liabilities Commodity 1 1 2 Interest rate 32 — 32 Total noncurrent derivative liabilities (4) 33 1 34 Total derivative liabilities $191 $ 93 $ 284 (1) Current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets.
Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location	The following tables present the gains and losses on Dominion Energy’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 (Effective (1) Amount of Gain (Loss) Reclassified to Income Increase (2) (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (90 ) Electric fuel and other energy-related purchases 14 Total commodity $ 64 $(76 ) $ — Interest rate (3) (18 ) (48 ) 39 Foreign currency (4) (6 ) (13 ) — Total $ 40 $(137 ) $39 Year Ended December 31, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 81 Purchased gas (2 ) Total commodity $ 1 $ 79 $ — Interest rate (3) (8 ) (52 ) (58 ) Foreign currency (4) 18 20 — Total $ 11 $ 47 $(58 ) Year Ended December 31, 2016 Derivative type and location of gains (losses): Commodity: Operating revenue $330 Purchased gas (13 ) Electric fuel and other energy-related purchases (10 ) Total commodity $164 $307 $ — Interest rate (3) (66 ) (31 ) (26 ) Foreign currency (4) (6 ) (17 ) — Total $ 92 $259 $(26 ) (1) Amounts deferred into AOCI have no associated effect in Dominion Energy’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 Energy’s Consolidated Statements of Income. (3) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges. (4) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in other income.
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance	Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in (1) Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $(28 ) $ 18 $ 2 Purchased gas 11 (3 ) 4 Electric fuel and other energy-related purchases (9 ) (59 ) (70 ) Other operations & maintenance — (1 ) 1 Total $(26 ) $(45 ) $(63 ) (1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion Energy’s Consolidated Statements of Income.
Virginia Electric and Power Company
Offsetting Assets	The tables below present Virginia Power’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets (1) Financial Cash Net Gross Assets (1) Financial Cash Collateral Net (millions) Commodity contracts: Over-the-counter $64 $ 6 $— $58 $155 $ 4 $— $151 Interest rate contracts: Over-the-counter 3 — — 3 — — — — Total derivatives, subject to a master netting or similar arrangement $67 $ 6 $— $61 $155 $ 4 $— $151 (1) Excludes $26 million and $11 million of derivative assets at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements.
Offsetting Liabilities	December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities (1) Financial Cash Net Gross Liabilities (1) Financial Cash Collateral Net (millions) Commodity contracts: Over-the-counter $ 6 $ 6 $— $— $ 4 $ 4 $— $ — Interest rate contracts: Over-the-counter 88 — — 88 57 — — 57 Total derivatives, subject to a master netting or similar arrangement $94 $ 6 $— $88 $61 $ 4 $— $57 (1) Excludes $9 million and $5 million of derivative liabilities at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements.
Schedule of Volume of Derivative Activity	The following table presents the volume of Virginia Power’s derivative activity at December 31, 2018. 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) 29 8 Basis 136 488 Electricity (MWh): Fixed price (1) 367,019 — FTRs 45,351,415 — Interest rate (2) $ 700,000,000 $ 1,200,000,000 (1) Includes options. (2) Maturity is determined based on final settlement period.
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following table presents selected information related to losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected to be Reclassified After-Tax Maximum (millions) Interest rate $ (13 ) $ (1 ) 396 months Total $ (13 ) $ (1 )
Fair Value of Derivatives	The following tables present the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Fair Value – Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ — $ 60 $ 60 Interest rate 3 — 3 Total current derivative assets (1) 3 60 63 Noncurrent Assets Commodity — 30 30 Total noncurrent derivative assets (2) — 30 30 Total derivative assets $ 3 $ 90 $ 93 LIABILITIES Current Liabilities Commodity $ — $ 15 $ 15 Interest rate 10 — 10 Total current derivative liabilities (3) 10 15 25 Noncurrent Liabilities Interest rate 78 — 78 Total noncurrent derivatives liabilities (4) 78 — 78 Total derivative liabilities $88 $ 15 $103 At December 31, 2017 ASSETS Current Assets Commodity $ — $ 75 $ 75 Total current derivative assets (1) — 75 75 Noncurrent Assets Commodity — 91 91 Total noncurrent derivative assets (2) — 91 91 Total derivative assets $ — $166 $166 LIABILITIES Current Liabilities Commodity $ — $ 9 $ 9 Interest rate 44 — 44 Total current derivative liabilities (3) 44 9 53 Noncurrent Liabilities Interest rate 13 — 13 Total noncurrent derivative liabilities (4) 13 — 13 Total derivative liabilities $57 $ 9 $ 66 (1) Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Virginia Power’s Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.
Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location	The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income: Derivatives in cash flow hedging Amount of (1) Amount of Increase (2) (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 2 $ (1 ) $ 39 Total $ 2 $ (1 ) $ 39 Year Ended December 31, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (8 ) $ (1 ) $ (58 ) Total $ (8 ) $ (1 ) $ (58 ) Year Ended December 31, 2016 Derivative type and location of gains (losses): Interest rate (3) $ (3 ) $ (1 ) $ (26 ) Total $ (3 ) $ (1 ) $ (26 ) (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 Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance	Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized (1) Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity (2) $2 $(57) $(70) Total $2 $(57) $(70) (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 Energy Gas Holdings, LLC
Offsetting Assets	The tables below present Dominion Energy Gas’ derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Gross Amounts Not Offset in the Consolidated Gross Assets Financial Cash Net Gross Assets Financial Cash Net (millions) Commodity contracts: Over-the-counter $ 3 $ — $ — $ 3 $ — $ — $ — $ — Foreign currency contracts: Over-the-counter 26 2 — 24 32 2 — 30 Total derivatives, subject to a master netting or similar arrangement $ 29 $ 2 $ — $ 27 $ 32 $ 2 $ — $ 30
Offsetting Liabilities	December 31, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Off set in the Consolidated Balance Sheet Gross Liabilities Financial Cash Net Gross Liabilities Financial Cash Net (millions) Commodity contracts Over-the-counter $ — $ — $ — $ — $ 6 $ — $ — $ 6 Interest rate contracts: Over-the-counter 17 — — 17 — — — — Foreign currency contracts: Over-the-counter 2 2 — — 2 2 — — Total derivatives, subject to a master netting or similar arrangement $ 19 $ 2 $ — $ 17 $ 8 $ 2 $ — $ 6
Schedule of Volume of Derivative Activity	The following table presents the volume of Dominion Energy Gas’ derivative activity at December 31, 2018. 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) 14,413,200 — Interest rate (1) $ 300,000,000 $ 750,000,000 Foreign currency (1)(2) $ — $ 280,000,000 (1) Maturity is determined based on final settlement period. (2) Euro equivalent volumes are €250,000,000.
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2018: AOCI After-Tax Amounts Expected After-Tax Maximum (millions) Commodities: NGLs $ 2 $ 2 3 months Interest rate (39 ) (4 ) 312 months Foreign currency 12 (2 ) 90 months Total $(25 ) $(4 )
Fair Value of Derivatives	The following table presents the fair values of Dominion Energy Gas’ derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Fair Value – Total (millions) At December 31, 2018 ASSETS Current Assets Commodity $ 3 $— $ 3 Total current derivative assets (1) 3 — 3 Noncurrent Assets Foreign currency 26 — 26 Total noncurrent derivative assets (2) 26 — 26 Total derivative assets $29 $— $29 LIABILITIES Current Liabilities Interest rate $ 9 $— $ 9 Foreign currency 2 — 2 Total current derivative liabilities (3) 11 — 11 Noncurrent Liabilities Interest rate 8 — 8 Total noncurrent derivative liabilities (4) 8 — 8 Total derivative liabilities $19 $— $19 At December 31, 2017 ASSETS Noncurrent Assets Foreign currency $32 $— $32 Total noncurrent derivative assets (2) 32 — 32 Total derivative assets $32 $— $32 LIABILITIES Current Liabilities Commodity $ 6 $— $ 6 Foreign currency 2 — 2 Total current derivative liabilities (3) 8 — 8 Total derivative liabilities $ 8 $— $ 8 (1) Current derivative assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (3) Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (4) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.
Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location	The following tables present the gains and losses on Dominion Energy Gas’ derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income: Derivatives in cash flow hedging Amount of Gain Derivatives (1) Amount of (millions) Year Ended December 31, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (8 ) Total commodity $ 1 $ (8 ) Interest rate (2) (18 ) (6 ) Foreign currency (3) (6 ) (13 ) Total $(23 ) $(27 ) Year Ended December 31, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ (8 ) Total commodity $(10 ) $ (8 ) Interest rate (2) — (5 ) Foreign currency (3) 18 20 Total $ 8 $ 7 Year Ended December 31, 2016 Derivative type and location of gains (losses): Commodity: Operating revenue $ 4 Total commodity $(12 ) $ 4 Interest rate (2) (8 ) (2 ) Foreign currency (3) (6 ) (17 ) Total $(26 ) $(15 ) (1) Amounts deferred into AOCI have no associated effect in Dominion Energy Gas’ Consolidated Statements of Income. (2) Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in interest and related charges. (3) Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in other income.
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance	Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized Year Ended December 31, 2018 2017 2016 (millions) Derivative type and location of gains (losses): Commodity Operating revenue $(11 ) $— $1 Total $(11 ) $— $1

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Earnings Per Share Computation	The following table presents the calculation of Dominion Energy’s basic and diluted EPS: 2018 2017 2016 (millions, except EPS) Net Income Attributable to Dominion Energy $ 2,447 $ 2,999 $ 2,123 Average shares of common stock outstanding – Basic 654.2 636.0 616.4 Net effect of dilutive securities (1) 0.7 — 0.7 Average shares of common stock outstanding – Diluted 654.9 636.0 617.1 Earnings Per Common Share – Basic $ 3.74 $ 4.72 $ 3.44 Earnings Per Common Share – Diluted $ 3.74 $ 4.72 $ 3.44 (1) Dilutive securities for 2018 consist primarily of forward sale agreements, effective April 2018 to December 2018. Dilutive securities for 2016 consist primarily of the 2013 Equity Units. See Notes 17 and 19 for more information.

Investments (Tables)

Investments (Tables)	12 Months Ended
	Dec. 31, 2018
Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds	decommissioning costs for its nuclear plants. Dominion Energy’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Fair (millions) December 31, 2018 Equity securities: (1) U.S. $1,741 $1,640 $(51) $3,330 Fixed income securities: (2) Corporate debt instruments 435 5 (9) 431 Government securities 1,092 17 (12) 1,097 Common/collective trust funds 76 — — 76 Cash equivalents and other (3) 4 — — 4 Total $3,348 $1,662 $(72) (4) $4,938 December 31, 2017 Equity securities: (2) U.S. $1,569 $1,857 $ — $3,426 Fixed income securities: (2) Corporate debt instruments 430 15 (1) 444 Government securities 1,039 27 (5) 1,061 Common/collective trust funds 60 — — 60 Cost method investments 68 — — 68 Cash equivalents and other (3) 34 — — 34 Total $3,200 $1,899 $ (6) (4) $5,093 (1) Effective January 2018, unrealized gains and losses on equity securities, including those previously classified as cost method investments, are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on equity securities (for 2017) and fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (3) Includes pending sales of securities of $5 million at December 31, 2017. (4) The fair value of securities in an unrealized loss position was $833 million and $565 million at December 31, 2018 and 2017, respectively.
Unrealized Gain Loss on Equity	The portion of unrealized gains and losses that relates to equity securities held within Dominion Energy’s nuclear decommissioning trusts is summarized below: Twelve (millions) Net losses recognized during the period $ (245 ) Less: Net gains recognized during the period on securities sold during the period (58 ) Unrealized losses recognized during the period on securities still held at December 31, 2018 (1) $ (303 ) (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Investments Classified by Contractual Maturity Date	The fair value of Dominion Energy’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 167 Due after one year through five years 389 Due after five years through ten years 376 Due after ten years 672 Total $ 1,604
Marketable Securities	Presented below is selected information regarding Dominion Energy’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2018 2017 2016 (millions) Proceeds from sales $ 1,804 $ 1,831 $ 1,422 Realized gains (1) 140 166 128 Realized losses (1) 91 71 55 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Other-Than-Temporary Impairment Losses	Dominion Energy recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows: Year Ended December 31, 2018 2017 2016 (millions) Total other-than-temporary impairment losses (1) $ 30 $ 44 $ 51 Losses recorded to the nuclear decommissioning trust regulatory liability — (16 ) (16 ) Losses recognized in other comprehensive income (before taxes) (30 ) (5 ) (12 ) Net impairment losses recognized in earnings $ — $ 23 $ 23 (1) Amounts include other-than-temporary impairment losses for debt securities of $5 million and $13 million at December 31, 2017 and 2016, respectively.
Investments Accounts Under Equity Method of Accounting	Investments that Dominion Energy and Dominion Energy Gas account for under the equity method of accounting are as follows: Company Ownership% Investment Description As of December 31, 2018 2017 (millions) Dominion Energy Atlantic Coast Pipeline 48 % $ 820 $ 382 Gas transmission system Blue Racer 50 % — 691 Midstream gas and related services Iroquois 50 % (1) 302 311 Gas transmission system Fowler Ridge 50 % 82 81 Wind-powered merchant generation facility Other (2) various 74 79 Total $ 1,278 $ 1,544 Dominion Energy Gas Iroquois 24.07 % $ 91 $ 95 Gas transmission system Total $ 91 $ 95 (1) Comprised of Dominion Energy Midstream’s interest of 25.93% and Dominion Energy Gas’ interest of 24.07%. See Note 15 for more information. (2) Liability of less than $1 million and $17 million associated with NedPower recorded to other deferred credits and other liabilities, on the Consolidated Balance Sheets as of December 31, 2018 and 2017, respectively. See additional discussion of NedPower below.
Virginia Electric and Power Company
Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds	decommissioning costs for its nuclear plants. Virginia Power’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Fair Value (millions) December 31, 2018 Equity securities: (1) U.S. $858 $751 $(24 ) $1,585 Fixed income securities: (2) Corporate debt instruments 224 2 (5 ) 221 Government securities 504 7 (5 ) 506 Common/collective trust funds 51 — — 51 Cash equivalents and other (3) 6 — — 6 Total $1,643 $760 $(34) (4) $2,369 December 31, 2017 Equity securities: (2) U.S. $ 734 $831 $— $1,565 Fixed income securities: (2) Corporate debt instruments 216 8 — 224 Government securities 482 13 (2 ) 493 Common/collective trust funds 27 — — 27 Cost method investments 68 — — 68 Cash equivalents and other (3) 22 — — 22 Total $1,549 $852 $(2 ) (4) $2,399 (1) Effective January 2018, unrealized gains and losses on equity securities, including those previously classified as cost method investments, are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on equity securities (for 2017) and fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (3) Includes pending sales of securities of $6 million at both December 31, 2018 and 2017. (4) The fair value of securities in an unrealized loss position was $404 million and $234 million at December 31, 2018 and 2017, respectively.
Unrealized Gain Loss on Equity	The portion of unrealized gains and losses that relates to equity securities held within Virginia Power’s nuclear decommissioning trusts is summarized below: Twelve (millions) Net losses recognized during the period $ (105 ) Less: Net gains recognized during the period on securities sold during the period (32 ) Unrealized losses recognized during the period on securities still held at December 31, 2018 (1) $ (137 ) (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Investments Classified by Contractual Maturity Date	The fair value of Virginia Power’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2018, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 54 Due after one year through five years 156 Due after five years through ten years 210 Due after ten years 358 Total $ 778
Marketable Securities	Presented below is selected information regarding Virginia Power’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2018 2017 2016 (millions) Proceeds from sales $ 887 $ 849 $ 733 Realized gains (1) 60 75 63 Realized losses (1) 27 30 27 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Other-Than-Temporary Impairment Losses	Virginia Power recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows: Year Ended December 31, 2018 2017 2016 (millions) Total other-than-temporary impairment losses (1) $ 15 $ 20 $ 26 Losses recorded to the nuclear decommissioning trust regulatory liability — (16 ) (16 ) Losses recognized in other comprehensive income (before taxes) (15 ) (2 ) (7 ) Net impairment losses recognized in earnings $ — $ 2 $ 3 (1) Amounts include other-than-temporary impairment losses for debt securities of $2 million and $8 million at December 31, 2017 and 2016 , respectively.

Regulatory Assets and Liabili_2

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2018
Regulated Operations [Abstract]
Schedule of Regulatory Assets	Regulatory assets and liabilities include the following: At December 31, 2018 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 96 70 Deferred nuclear refueling outage costs (3) 69 54 Unrecovered gas costs (4) 14 38 Other 143 109 Regulatory assets-current 496 294 Unrecognized pension and other postretirement benefit costs (5) 1,497 1,336 Deferred rate adjustment clause costs (2) 329 401 Utility reform legislation (6) 204 147 PJM transmission rates (7) 192 222 Derivatives (8) 184 223 Deferred cost of fuel used in electric generation (1) 83 — Other 187 151 Regulatory assets-noncurrent 2,676 2,480 Total regulatory assets $ 3,172 $ 2,774 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 117 $ 101 Cost-of-service (10) 104 — Reserve for rate credits to electric utility customers (11) 71 — Other 64 92 Regulatory liabilities-current (12) 356 193 Income taxes refundable through future rates (13) 4,071 4,058 Provision for future cost of removal and AROs (9) 1,409 1,384 Nuclear decommissioning trust (14) 1,070 1,121 Derivatives ( 8 ) 25 69 Other 265 284 Regulatory liabilities-noncurrent 6,840 6,916 Total regulatory liabilities $ 7,196 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 78 56 Deferred nuclear refueling outage costs (3) 69 54 Other 103 72 Regulatory assets-current 424 205 Deferred rate adjustment clause costs (2) 230 312 PJM transmission rates (7) 192 222 Derivatives (8) 151 190 Deferred cost of fuel used in electric generation (1) 83 — Other 81 86 Regulatory assets-noncurrent 737 810 Total regulatory assets $ 1,161 $ 1,015 Regulatory liabilities: Cost-of-service (10) $ 95 $ — Provision for future cost of removal (9) 92 80 Reserve for rate credits to customers (11) 71 — Other 41 47 Regulatory liabilities-current 299 127 Income taxes refundable through future rates (13) 2,579 2,581 Nuclear decommissioning trust (14) 1,070 1,121 Provision for future cost of removal (9) 940 915 Derivatives ( 8 ) 25 69 Other 33 74 Regulatory liabilities-noncurrent 4,647 4,760 Total regulatory liabilities $ 4,946 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 18 $ 14 Unrecovered gas costs (4) 9 8 Other 2 4 Regulatory assets-current (16) 29 26 Unrecognized pension and other postretirement benefit costs (5) 392 258 Utility reform legislation (6) 204 147 Deferred rate adjustment clause costs (2) 99 89 Other 32 17 Regulatory assets-noncurrent 727 511 Total regulatory assets $ 756 $ 537 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 14 $ 13 PIPP (15) 3 20 Other 4 5 Regulatory liabilities-current (12) 21 38 Income taxes refundable through future rates (13) 1,011 998 Provision for future cost of removal and AROs (9) 158 160 Cost-of-service (10) 19 — Other 97 69 Regulatory liabilities-noncurrent 1,285 1,227 Total regulatory liabilities $ 1,306 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. See Note 13 for more information. (2) Primarily reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power and deferrals of costs associated with certain current and prospective rider projects for Dominion Energy 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 or overrecovered gas costs at regulated gas operations, which are recovered or refunded 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 Energy and Dominion Energy Gas’ rate-regulated subsidiaries. (6) Ohio legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date (7) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (10) Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at the Companies’ regulated electric generation and electric and natural gas distribution operations. See Note 13 for more information. (11) Charge associated with Virginia legislation enacted in March 2018 that requires one-time (12) Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas’ Consolidated Balance Sheets. (13) Amounts recorded to pass the effect of reduced income tax rates from the 2017 Tax Reform Act to customers in future periods, which will reverse at the weighted average tax rate that was used to build the reserves over the remaining book life of the property, net of amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity. (14) 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. (15) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information. (16) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities include the following: At December 31, 2018 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 96 70 Deferred nuclear refueling outage costs (3) 69 54 Unrecovered gas costs (4) 14 38 Other 143 109 Regulatory assets-current 496 294 Unrecognized pension and other postretirement benefit costs (5) 1,497 1,336 Deferred rate adjustment clause costs (2) 329 401 Utility reform legislation (6) 204 147 PJM transmission rates (7) 192 222 Derivatives (8) 184 223 Deferred cost of fuel used in electric generation (1) 83 — Other 187 151 Regulatory assets-noncurrent 2,676 2,480 Total regulatory assets $ 3,172 $ 2,774 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 117 $ 101 Cost-of-service (10) 104 — Reserve for rate credits to electric utility customers (11) 71 — Other 64 92 Regulatory liabilities-current (12) 356 193 Income taxes refundable through future rates (13) 4,071 4,058 Provision for future cost of removal and AROs (9) 1,409 1,384 Nuclear decommissioning trust (14) 1,070 1,121 Derivatives ( 8 ) 25 69 Other 265 284 Regulatory liabilities-noncurrent 6,840 6,916 Total regulatory liabilities $ 7,196 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 174 $ 23 Deferred rate adjustment clause costs (2) 78 56 Deferred nuclear refueling outage costs (3) 69 54 Other 103 72 Regulatory assets-current 424 205 Deferred rate adjustment clause costs (2) 230 312 PJM transmission rates (7) 192 222 Derivatives (8) 151 190 Deferred cost of fuel used in electric generation (1) 83 — Other 81 86 Regulatory assets-noncurrent 737 810 Total regulatory assets $ 1,161 $ 1,015 Regulatory liabilities: Cost-of-service (10) $ 95 $ — Provision for future cost of removal (9) 92 80 Reserve for rate credits to customers (11) 71 — Other 41 47 Regulatory liabilities-current 299 127 Income taxes refundable through future rates (13) 2,579 2,581 Nuclear decommissioning trust (14) 1,070 1,121 Provision for future cost of removal (9) 940 915 Derivatives ( 8 ) 25 69 Other 33 74 Regulatory liabilities-noncurrent 4,647 4,760 Total regulatory liabilities $ 4,946 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 18 $ 14 Unrecovered gas costs (4) 9 8 Other 2 4 Regulatory assets-current (16) 29 26 Unrecognized pension and other postretirement benefit costs (5) 392 258 Utility reform legislation (6) 204 147 Deferred rate adjustment clause costs (2) 99 89 Other 32 17 Regulatory assets-noncurrent 727 511 Total regulatory assets $ 756 $ 537 Regulatory liabilities: Provision for future cost of removal and AROs (9) $ 14 $ 13 PIPP (15) 3 20 Other 4 5 Regulatory liabilities-current (12) 21 38 Income taxes refundable through future rates (13) 1,011 998 Provision for future cost of removal and AROs (9) 158 160 Cost-of-service (10) 19 — Other 97 69 Regulatory liabilities-noncurrent 1,285 1,227 Total regulatory liabilities $ 1,306 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. See Note 13 for more information. (2) Primarily reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power and deferrals of costs associated with certain current and prospective rider projects for Dominion Energy 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 or overrecovered gas costs at regulated gas operations, which are recovered or refunded 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 Energy and Dominion Energy Gas’ rate-regulated subsidiaries. (6) Ohio legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date (7) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (10) Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at the Companies’ regulated electric generation and electric and natural gas distribution operations. See Note 13 for more information. (11) Charge associated with Virginia legislation enacted in March 2018 that requires one-time (12) Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas’ Consolidated Balance Sheets. (13) Amounts recorded to pass the effect of reduced income tax rates from the 2017 Tax Reform Act to customers in future periods, which will reverse at the weighted average tax rate that was used to build the reserves over the remaining book life of the property, net of amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity. (14) 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. (15) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information. (16) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2018
Regulated Operations [Abstract]
Summary of Additional Significant Riders Associated with Virginia Power Projects	Additional significant riders associated with various Virginia Power projects are as follows: Rider Name Application Date Approval Date Rate Year Beginning Total Increase Rider S June 2018 February 2019 April 2019 $ 215 $ (3 ) Rider GV June 2018 February 2019 April 2019 120 38 Rider W June 2018 February 2019 April 2019 105 (4 ) Rider R June 2018 February 2019 April 2019 57 (9 ) Rider B June 2018 February 2019 April 2019 38 (9 ) Rider BW October Pending September 2019 123 7 Rider US-2 October Pending September 2019 16 3 Rider E December Pending November 2019 114 N/A
Summary of Additional Significant Virginia Power Electric Transmission Projects Approved and Applied	Additional significant Virginia Power electric transmission projects approved and applied for in 2018 are as follows: Description and Location of Project Application Date Approval Date Type of Line Miles Lines Cost (millions) Rebuild and operate existing 115 kV transmission lines between the Possum Point Switching Station and Northern Virginia Electric Cooperative’s Smoketown delivery point June 2017 February 2018 230 kV 9 $ 20 Rebuild and operate between the Dooms substation and the Valley substation, along with associated substation work September 2017 September 2018 500 kV 18 65 Build and operate between the Idylwood and Tysons substations, along with associated substation work November 2017 September 2018 230 kV 4 125 Rebuild and operate between the Chesterfield and Hopewell substations, along with associated substation work May 2018 November 2018 230 kV 8 30 Rebuild and operate between the Chesterfield and Lakeside substations, along with associated substation work May 2018 December 2018 230 kV 21 35 Rebuild and operate between the Landstown and Thrasher substations, along with associated substation work June 2018 December 2018 230 kV 8.5 20 Partial rebuild of overhead transmission lines in Alleghany County, Virginia and Covington, Virginia August 2018 Pending 138 kV 5 15 Build a new substation and connect three existing transmission lines thereto in Fluvanna County, Virginia October 2018 Pending 230 kV <1 30

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Changes to Asset Retirement Obligations	The changes to AROs during 2017 and 2018 were as follows: Amount (millions) Dominion Energy AROs at December 31, 2016 $ 2,485 Obligations incurred during the period 37 Obligations settled during the period (214 ) Revisions in estimated cash flows 7 Accretion 117 AROs at December 31, 2017 (1) $ 2,432 Obligations incurred during the period 20 Obligations settled during the period (159 ) Revisions in estimated cash flows (2) 120 Accretion 119 AROs at December 31, 2018 (1) $ 2,532 Virginia Power AROs at December 31, 2016 $ 1,443 Obligations incurred during the period 11 Obligations settled during the period (152 ) Revisions in estimated cash flows (1 ) Accretion 64 AROs at December 31, 2017 $ 1,365 Obligations incurred during the period 14 Obligations settled during the period (119 ) Revisions in estimated cash flows (2) 120 Accretion 65 AROs at December 31, 2018 $ 1,445 Dominion Energy Gas AROs at December 31, 2016 $ 156 Obligations incurred during the period 2 Obligations settled during the period (7 ) Accretion 9 AROs at December 31, 2017 (3) $ 160 Obligations incurred during the period 4 Obligations settled during the period (6 ) Accretion 9 AROs at December 31, 2018 (3) $ 167 (1) Includes $263 million and $282 million reported in other current liabilities at December 31, 2017, and 2018, respectively. (2) Reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information. (3) Includes $146 million and $153 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2017 and 2018, respectively.

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2018
Schedule of Accumulated Other Comprehensive Income (Loss)	Presented in the table below is a summary of AOCI by component: At December 31, 2018 2017 (millions) Dominion Energy Net deferred losses on derivatives-hedging activities, net of $79 and $188 tax $ (234 ) $ (301 ) Net unrealized gains on nuclear decommissioning trust funds, net of $— and $(419) tax 2 747 Net unrecognized pension and other postretirement benefit costs, net of $519 and $692 tax (1,465 ) (1,101 ) Other comprehensive loss from equity method investees, net of $— and $2 tax (2 ) (3 ) Total AOCI, including noncontrolling interest $ (1,699 ) $ (658 ) Less other comprehensive income attributable to noncontrolling interest 1 1 Total AOCI, excluding noncontrolling interest $ (1,700 ) $ (659 ) Virginia Power Net deferred losses on derivatives-hedging activities, net of $4 and $8 tax $ (13 ) $ (12 ) Net unrealized gains on nuclear decommissioning trust funds, net of $— and $(47) tax 1 74 Total AOCI $ (12 ) $ 62 Dominion Energy Gas Net deferred losses on derivatives-hedging activities, net of $8 and $15 tax $ (25 ) $ (23 ) Net unrecognized pension costs, net of $56 and $59 tax (144 ) (75 ) Total AOCI $ (169 ) $ (98 ) D OMINION NERGY The following table presents Dominion Energy’s changes in AOCI by component, net of tax: Deferred Unrealized Unrecognized Other Total (millions) Year Ended December 31, 2018 Beginning balance $(302 ) $ 747 $(1,101 ) $(3 ) $(659 ) Other comprehensive income before reclassifications: gains (losses) 30 (18 ) (215 ) 1 (202 ) Amounts reclassified from AOCI: (gains) losses (1) 102 5 78 — 185 Net current period other comprehensive income (loss) 132 (13) (137 ) 1 (17 ) Cumulative-effect of changes in accounting principle (64 ) (732) (227 ) — (1,023 ) Less other comprehensive income (loss) attributable to noncontrolling interest 1 — — — 1 Ending balance $(235 ) $2 $(1,465 ) $(2 ) $(1,700 ) Year Ended December 31, 2017 Beginning balance $(280 ) $ 569 $(1,082 ) $(6 ) $ (799 ) Other comprehensive income before reclassifications: gains (losses) 8 215 (69 ) 3 157 Amounts reclassified from AOCI: (gains) losses (1) (29 ) (37 ) 50 — (16 ) Net current period other comprehensive income (loss) (21 ) 178 (19 ) 3 141 Less other comprehensive income (loss) attributable to noncontrolling interest 1 — — — 1 Ending balance $(302 ) $ 747 $(1,101 ) $(3 ) $ (659 ) (1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	The following table presents Dominion Energy’s reclassifications out of AOCI by component: Details about AOCI components Amounts Affected line item in the (millions) Year Ended December 31, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $90 Operating revenue (14 ) Electric fuel and other Interest rate contracts 48 Interest and related charges Foreign currency contracts 13 Other Income Total 137 Tax (35 ) Income tax expense Total, net of tax $102 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $7 Other income Total 7 Tax (2 ) Income tax expense Total, net of tax $5 Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $(21 ) Other income Amortization of actuarial losses 120 Other income Total 99 Tax (21 ) Income tax expense Total, net of tax $78 Year Ended December 31, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $(81 ) Operating revenue 2 Purchased gas Interest rate contracts 52 Interest and related charges Foreign currency contracts (20 ) Other Income Total (47 ) Tax 18 Income tax expense Total, net of tax $(29 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $(81 ) Other income Impairment 23 Other income Total (58 ) Tax 21 Income tax expense Total, net of tax $(37 ) Unrecognized pension and other postretirement benefit costs: Prior-service costs (credits) $(21 ) Other income Actuarial losses 103 Other income Total 82 Tax (32 ) Income tax expense Total, net of tax $50
Summary of Restricted Stock Activity	The following table provides a summary of restricted stock activity for the years ended December 31, 2018, 2017 and 2016: Shares Weighted —average (thousands) Nonvested at December 31, 2015 855 $66.16 Granted 372 71.67 Vested (301 ) 56.83 Cancelled and forfeited (40 ) 71.75 Nonvested at December 31, 2016 886 $71.40 Granted 454 74.24 Vested (287 ) 68.90 Cancelled and forfeited (10 ) 72.37 Nonvested at December 31, 2017 1,043 $73.32 Granted 534 72.92 Vested (316 ) 73.59 Cancelled and forfeited (53 ) 74.25 Nonvested at December 31, 2018 1,208 $73.03
Virginia Electric and Power Company
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Virginia Power’s changes in AOCI by component, net of tax: Deferred Unrealized Total (millions) Year Ended December 31, 2018 Beginning balance $ (12) $ 74 $ 62 Other comprehensive income before reclassifications: gains (losses) 1 — 1 Amounts reclassified from AOCI: (gains) losses (1) 1 — 1 Net current period other comprehensive income (loss) 2 — 2 Cumulative-effect of changes in accounting principle (3 ) (73 ) (76 ) Ending balance $ (13 ) $ 1 $(12 ) Year Ended December 31, 2017 Beginning balance $ (8 ) $ 54 $ 46 Other comprehensive income before reclassifications: gains (losses) (5 ) 24 19 Amounts reclassified from AOCI: gains (losses) (1) 1 (4 ) (3 ) Net current period other comprehensive income (loss) (4 ) 20 16 Ending balance $ (12 ) $ 74 $ 62 (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 Affected line item in the (millions) Year Ended December 31, 2018 (Gains) losses on cash flow hedges: Interest rate contracts $ 1 Interest and related charges Total 1 Tax — Income tax expense Total, net of tax $ 1 Year Ended December 31, 2017 (Gains) losses on cash flow hedges: Interest rate contracts $ 1 Interest and related charges 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 $(9 ) Other income Impairment 2 Other income Total (7 ) Tax 3 Income tax expense Total, net of tax $(4 )
Dominion Energy Gas Holdings, LLC
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Dominion Energy Gas’ changes in AOCI by component, net of tax: Deferred gains Unrecognized Total (millions) Year Ended December 31, 2018 Beginning balance $(23 ) $ (75 ) $ (98 ) Other comprehensive income before reclassifications: gains (losses) (17 ) (52 ) (69 ) Amounts reclassified from AOCI: (gains) losses (1) 20 4 24 Net current period other comprehensive income (loss) 3 (48 ) (45 ) Cumulative-effect of changes in accounting principle (5 ) (21 ) (26 ) Ending balance $(25 ) $(144 ) $ (169 ) Year Ended December 31, 2017 Beginning balance $(24 ) $ (99 ) $ (123 ) Other comprehensive income before reclassifications: gains (losses) 5 20 25 Amounts reclassified from AOCI: gains (losses) (1) (4 ) 4 — Net current period other comprehensive income (loss) 1 24 25 Ending balance $(23 ) $ (75 ) $ (98 ) (1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	The following table presents Dominion Energy Gas’ reclassifications out of AOCI by component: Details about AOCI components Amounts Affected line item in the (millions) Year Ended December 31, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 8 Operating revenue Interest rate contracts 6 Interest and related charges Foreign currency contracts 13 Other income Total 27 Tax (7 ) Income tax expense Total, net of tax $ 20 Unrecognized pension costs: Actuarial losses $ 6 Other income Total 6 Tax (2 ) Income tax expense Total, net of tax $ 4 Year Ended December 31, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 8 Operating revenue Interest rate contracts 5 Interest and related charges Foreign currency contracts (20 ) Other income Total (7 ) Tax 3 Income tax expense Total, net of tax $ (4 ) Unrecognized pension costs: Actuarial losses $ 6 Other income Total 6 Tax (2 ) Income tax expense Total, net of tax $ 4

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2018
Retirement 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 Energy and Dominion Energy Gas (for employees represented by collective bargaining units): Pension Benefits Other Postretirement Benefits Year Ended December 31, 2018 2017 2018 2017 (millions, except percentages) Dominion Energy Changes in benefit obligation: Benefit obligation at beginning of year $ 9,052 $ 8,132 $ 1,529 $ 1,478 Service cost 157 138 27 26 Interest cost 337 345 56 60 Benefits paid (358 ) (323 ) (87 ) (83 ) Actuarial (gains) losses during the year (688 ) 830 (158 ) 119 Plan amendments (1) — 5 (4 ) (73 ) Settlements and curtailments (2) — (75 ) — 2 Benefit obligation at end of year $ 8,500 $ 9,052 $ 1,363 $ 1,529 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 8,062 $ 7,016 $ 1,729 $ 1,512 Actual return (loss) on plan assets (513 ) 1,327 (92 ) 236 Employer contributions 6 118 12 13 Benefits paid (358 ) (323 ) (68 ) (32 ) Settlements (2) — (76 ) — — Fair value of plan assets at end of year $ 7,197 $ 8,062 $ 1,581 $ 1,729 Funded status at end of year $ (1,303 ) $ (990 ) $ 218 $ 200 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 1,003 $ 1,117 $ 276 $ 261 Other current liabilities (34 ) (8 ) (2 ) — Noncurrent pension and other postretirement benefit liabilities (2,272 ) (2,099 ) (56 ) (61 ) Net amount recognized $ (1,303 ) $ (990 ) $ 218 $ 200 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.42%–4.43% 3.80%–3.81% 4.37%–4.38% 3.76% Weighted average rate of increase for compensation 4.32% 4.09% 4.30%-4.55% 3.95%-4.11% Dominion Energy Gas Changes in benefit obligation: Benefit obligation at beginning of year $ 773 $ 683 $ 290 $ 320 Service cost 18 15 4 4 Interest cost 29 30 11 12 Benefits paid (34 ) (33 ) (18 ) (19 ) Actuarial (gains) losses during the year (56 ) 78 (27 ) 34 Plan amendments (1) — — (4 ) (61 ) Benefit obligation at end of year $ 730 $ 773 $ 256 $ 290 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 1,803 $ 1,542 $ 333 $ 299 Actual return (loss) on plan assets (113 ) 294 (16 ) 41 Employer contributions — — 12 12 Benefits paid (34 ) (33 ) (18 ) (19 ) Fair value of plan assets at end of year $ 1,656 $ 1,803 $ 311 $ 333 Funded status at end of year $ 926 $ 1,030 $ 55 $ 43 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 926 $ 1,030 $ 63 $ 57 Noncurrent pension and other postretirement benefit liabilities (3) — — (8 ) (14 ) Net amount recognized $ 926 $ 1,030 $ 55 $ 43 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 4.42 % 3.81 % 4.37 % 3.76 % Weighted average rate of increase for compensation 4.55 % 4.11 % n/a n/a (1) 2017 amounts relate primarily to a plan amendment that changed post-65 (2) 2017 amount relates primarily to settlement and curtailment as a result of the voluntary and involuntary separation programs at Dominion Energy Questar. (3) Reflected in other deferred credits and other liabilities in Dominion Energy 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 Energy and Dominion Energy Gas (for employees represented by collective bargaining units): Pension Benefits Other Postretirement Benefits As of December 31, 2018 2017 2018 2017 (millions) Dominion Energy Benefit obligation $ 7,705 $ 8,209 $164 $191 Fair value of plan assets 5,398 6,103 136 156 Dominion Energy Gas Benefit obligation $ — $ — $134 $157 Fair value of plan assets — — 126 143
Accumulated benefit obligation in excess of plan assets	The following table provides information on the ABO and fair value of plan assets for Dominion Energy’s pension plans with an ABO in excess of plan assets: As of December 31, 2018 2017 (millions) Accumulated benefit obligation $ 7,056 $ 7,392 Fair value of plan assets 5,398 6,103
Benefit payments expected future service	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) plans: Estimated Future Benefit Payments Pension Benefits Other Postretirement Benefits (millions) Dominion Energy 2019 $407 $98 2020 405 99 2021 426 99 2022 442 99 2023 465 98 2024-2028 2,548 461 Dominion Energy Gas 2019 $37 $19 2020 39 19 2021 40 19 2022 42 19 2023 43 19 2024-2028 223 90
Fair values of pension and post retirement plan assets by asset category	The fair values of Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) pension plan assets by asset category are as follows: At December 31, 2018 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 17 $ 1 $— $ 18 $ 18 $ — $— $ 18 Common and preferred stocks: U.S. 1,645 — — 1,645 1,902 — — 1,902 International 1,061 — — 1,061 1,151 — — 1,151 Insurance contracts — 318 — 318 — 352 — 352 Corporate debt instruments 23 729 — 752 41 729 — 770 Government securities 25 605 — 630 9 676 — 685 Total recorded at fair value $ 2,771 $ 1,653 $— $ 4,424 $ 3,121 $ 1,757 $— $ 4,878 Assets recorded at NAV (1) Common/collective trust funds 1,849 2,272 Alternative investments: Real estate funds 108 111 Private equity funds 633 606 Debt funds 155 161 Hedge funds 17 19 Total recorded at NAV $ 2,762 $ 3,169 Total investments (2) $ 7,186 $ 8,047 Dominion Energy Gas Cash and cash equivalents $ 4 $ — $— $ 4 $ 4 $ — $— $ 4 Common and preferred stocks: U.S. 378 — — 378 425 — — 425 International 244 — — 244 257 — — 257 Insurance contracts — 73 — 73 — 79 — 79 Corporate debt instruments 5 168 — 173 9 163 — 172 Government securities 6 139 — 145 2 151 — 153 Total recorded at fair value $ 637 $ 380 $— $ 1,017 $ 697 $ 393 $— $ 1,090 Assets recorded at NAV (1) Common/collective trust funds 425 509 Alternative investments: Real estate funds 25 25 Private equity funds 146 135 Debt funds 36 36 Hedge funds 4 4 Total recorded at NAV $ 636 $ 709 Total investments (3) $ 1,653 $ 1,799 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $12 million, net accrued income of $21 million, and includes net assets related to pending purchases of securities of $22 million at December 31, 2018. Excludes net assets related to pending sales of securities of $11 million, net accrued income of $19 million, and includes net assets related to pending purchases of securities of $15 million at December 31, 2017. (3) Excludes net assets related to pending sales of securities of $3 million, net accrued income of $5 million, and includes net assets related to pending purchases of securities of $5 million at December 31, 2018. Excludes net assets related to pending sales of securities of $3 million, net accrued income of $4 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2017. The fair values of Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) other postretirement plan assets by asset category are as follows: At December 31, 2018 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $1 $1 $— $ 2 $1 $2 $— $3 Common and preferred stocks: U.S. 554 — — 554 636 — — 636 International 170 — — 170 196 — — 196 Insurance contracts — 19 — 19 — 21 — 21 Corporate debt instruments 1 44 — 45 2 44 — 46 Government securities 2 37 — 39 1 41 — 42 Total recorded at fair value $728 $101 $— $ 829 $836 $108 $— $944 Assets recorded at NAV (1) Common/collective trust funds 650 689 Alternative investments: Real estate funds 10 9 Private equity funds 80 73 Debt funds 10 11 Hedge funds 1 1 Total recorded at NAV $ 751 $783 Total investments (2) $ 1,580 $1,727 Dominion Energy Gas Common and preferred stocks: U.S. $113 $— $— $ 113 $130 $— $— $130 International 30 — — 30 33 — — 33 Total recorded at fair value $143 $— $— $ 143 $163 $— $— $163 Assets recorded at NAV (1) Common/collective trust funds 148 154 Alternative investments: Real estate funds 2 1 Private equity funds 18 15 Debt funds — — Total recorded at NAV $ 168 $170 Total investments $ 311 $333 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2018. Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $1 million at December 31, 2017.
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 Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) plans are as follows: Pension Benefits Other Postretirement Benefits Year Ended December 31, 2018 2017 2016 2018 2017 2016 (millions, except percentages) Dominion Energy Service cost $ 157 $ 138 $ 118 $ 27 $ 26 $ 31 Interest cost 337 345 317 56 60 65 Expected return on plan assets (663 ) (639 ) (573 ) (143 ) (128 ) (118 ) Amortization of prior service (credit) cost 1 1 1 (52 ) (51 ) (35 ) Amortization of net actuarial loss 193 162 111 11 13 8 Settlements and curtailments — — 1 — — — Net periodic benefit (credit) cost $ 25 $ 7 $ (25 ) $ (101 ) $ (80 ) $ (49 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 490 $ 142 $ 931 $ 78 $ 12 $ 178 Prior service (credit) cost — 5 — (4 ) (73 ) (216 ) Settlements and curtailments — 1 (1 ) — 2 — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (193 ) (162 ) (111 ) (11 ) (13 ) (8 ) Amortization of prior service credit (cost) (1 ) (1 ) (1 ) 52 51 35 Total recognized in other comprehensive income and regulatory assets and liabilities $ 296 $ (15 ) $ 818 $ 115 $ (21 ) $ (11 ) Significant assumptions used to determine periodic cost: Discount rate 3.80%-3.8 1% 3.31%-4.5 0% 2.87%-4.9 9% 3.76% 3.92%-4.4 7% 3.56%-4.9 4% Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % Weighted average rate of increase for compensation 4.09 % 4.09 % 4.22 % 3.95%-4.1 1% 3.29 % 4.22 % Healthcare cost trend rate (1) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate (1)(2) 2022 2021 2020 Dominion Energy Gas Service cost $ 18 $ 15 $ 13 $ 4 $ 4 $ 5 Interest cost 29 30 30 11 12 14 Expected return on plan assets (150 ) (141 ) (134 ) (28 ) (24 ) (23 ) Amortization of prior service (credit) cost — — — (4 ) (3 ) 1 Amortization of net actuarial loss 19 16 13 3 2 1 Net periodic benefit (credit) cost $ (84 ) $ (80 ) $ (78 ) $ (14 ) $ (9 ) $ (2 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ 207 $ (75 ) $ 91 $ 16 $ 18 $ 28 Prior service cost — — — (4 ) (61 ) — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (19 ) (16 ) (13 ) (3 ) (2 ) (1 ) Amortization of prior service credit (cost) — — — 4 3 (1 ) Total recognized in other comprehensive income and regulatory assets and liabilities $ 188 $ (91 ) $ 78 $ 13 $ (42 ) $ 26 Significant assumptions used to determine periodic cost: Discount rate 3.81 % 4.50 % 4.99 % 3.81 % 4.47 % 4.93 % Expected long-term rate of return on plan assets 8.75 % 8.75 % 8.75 % 8.50 % 8.50 % 8.50 % Weighted average rate of increase for compensation 4.11 % 4.11 % 3.93 % 4.55 % 4.11 % 3.93 % Healthcare cost trend rate (1) 7.00 % 7.00 % 7.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate (1) 2022 2021 2020 (1) Assumptions used to determine net periodic cost for the following year. (2) 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 Energy and Dominion Energy 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, 2018 2017 2018 2017 (millions) Dominion Energy Net actuarial loss $ 3,477 $ 3,181 $ 350 $ 283 Prior service (credit) cost 7 8 (393 ) (440 ) Total (1) $ 3,484 $ 3,189 $ (43 ) $ (157 ) Dominion Energy Gas Net actuarial loss $ 555 $ 367 $ 89 $ 76 Prior service (credit) cost — — (52 ) (52 ) Total (2) $ 555 $ 367 $ 37 $ 24 (1) As of December 31, 2018, of the $3.5 billion and $(43) million related to pension benefits and other postretirement benefits, $2.0 billion and $(41) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2017, of the $3.2 billion and $(157) million related to pension benefits and other postretirement benefits, $1.9 billion and $(87) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. (2) As of December 31, 2018, of the $555 million related to pension benefits, $200 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $37 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2017, of the $367 million related to pension benefits, $134 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $24 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 2019	The following table provides the components of AOCI and regulatory assets and liabilities for Dominion Energy and Dominion Energy Gas’ (for employees represented by collective bargaining units) plans as of December 31, 2018 that are expected to be amortized as components of net periodic benefit (credit) cost in 2019: Pension Benefits Other Benefits (millions) Dominion Energy Net actuarial loss $155 $ 18 Prior service (credit) cost 1 (52) Dominion Energy Gas Net actuarial loss $ 19 $ 4 Prior service (credit) cost — (4 )
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 Energy and Dominion Energy 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 Energy Effect on net periodic cost for 2019 $ 20 $ (16) Effect on other postretirement benefit obligation at December 31, 2018 130 (110) Dominion Energy Gas Effect on net periodic cost for 2019 $ 4 $ (3) Effect on other postretirement benefit obligation at December 31, 2018 25 (22)

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2018
Virginia Electric and Power Company
Schedule of Related Party Transactions	Presented below are significant transactions with DES and other affiliates: Year Ended December 31, 2018 2017 2016 (millions) Commodity purchases from affiliates $ 930 $ 674 $ 571 Services provided by affiliates (1) 450 453 454 Services provided to affiliates 24 25 22 (1) Includes capitalized expenditures of $145 million, $144 million and $144 million for the year ended December 31, 2018, 2017 and 2016, respectively.
Dominion Energy Gas Holdings, LLC
Schedule of Related Party Transactions	The costs of these services follow: Year Ended December 31, 2018 2017 2016 (millions) Sales of natural gas and transportation and storage services to affiliates $ 58 $ 70 $ 69 Purchases of natural gas from affiliates 6 5 9 Services provided by related parties (1) 131 143 141 Services provided to related parties (2) 216 156 128 (1) Includes capitalized expenditures of $37 million, $45 million and $49 million for the year ended December 31, 2018, 2017 and 2016, respectively. (2) Amounts primarily attributable to Atlantic Coast Pipeline, a related party VIE.
Schedule of Related Party Transactions	The following table presents affiliated and related party balances reflected in Dominion Energy Gas’ Consolidated Balance Sheets: At December 31, 2018 2017 (millions) Other receivables (1) $ 13 $ 12 Customer receivables from related parties 1 1 Imbalances receivable from affiliates 1 1 Imbalances payable to affiliates (2) 13 — Affiliated notes receivable (3) 16 20 (1) Represents amounts due from Atlantic Coast Pipeline, a related party VIE. (2) Amounts are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (3) Amounts are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.

Operating Segments (Tables)

Operating Segments (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting Disclosure Other Information	A description of the operations included in the Companies’ primary operating segments is as follows: Primary Operating Description of Operations Dominion Virginia Dominion Power Delivery Regulated electric distribution X X Regulated electric transmission X X Power Generation Regulated electric generation fleet X X Merchant electric generation fleet X Gas Infrastructure Gas transmission and storage X (1) X Gas distribution and storage X X Gas gathering and processing X X LNG terminalling and storage X Nonregulated retail energy marketing X (1) Includes remaining producer services activities.
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Energy’s operations: Year Ended December 31, Power Delivery Power Generation Gas Infrastructure Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2018 Total revenue from external customers $ 2,206 $ 7,104 $ 4,221 $ (208 ) $ 43 $ 13,366 Intersegment revenue 23 11 27 674 (735 ) — Total operating revenue 2,229 7,115 4,248 466 (692 ) 13,366 Depreciation, depletion and amortization 625 746 615 14 — 2,000 Impairment of assets and related charges — 1 8 394 — 403 Gains on sales of assets — 6 (186 ) (200 ) — (380 ) Equity in earnings of equity method investees — 18 178 1 — 197 Interest income — 90 64 126 (196 ) 84 Interest and related charges 265 374 268 782 (196 ) 1,493 Income tax expense (benefit) 160 294 330 (204 ) — 580 Net income (loss) attributable to Dominion Energy 587 1,254 1,214 (608 ) — 2,447 Investment in equity method investees — 82 1,159 37 — 1,278 Capital expenditures 1,564 1,321 1,415 105 — 4,405 Total assets (billions) 17.8 28.2 31.5 11.2 (10.8 ) 77.9 2017 Total revenue from external customers $ 2,206 $ 6,676 $ 2,832 $ 16 $ 856 $ 12,586 Intersegment revenue 22 10 834 610 (1,476 ) — Total operating revenue 2,228 6,686 3,666 626 (620 ) 12,586 Depreciation, depletion and amortization 593 747 522 43 — 1,905 Impairment of assets and related charges — — — 15 — 15 Gains on sales of assets — — (147 ) — — (147 ) Equity in earnings of equity method investees — (181 ) 159 4 — (18 ) Interest income 4 92 45 96 (155 ) 82 Interest and related charges 265 342 109 644 (155 ) 1,205 Income tax expense (benefit) 334 373 487 (1,224 ) — (30 ) Net income (loss) attributable to Dominion Energy 531 1,181 898 389 — 2,999 Investment in equity method investees — 81 1,422 41 — 1,544 Capital expenditures 1,433 2,275 2,149 52 — 5,909 Total assets (billions) 16.7 29.0 28.0 12.0 (9.1 ) 76.6 2016 Total revenue from external customers $ 2,210 $ 6,747 $ 2,069 $ (7 ) $ 718 $ 11,737 Intersegment revenue 23 10 697 609 (1,339 ) — Total operating revenue 2,233 6,757 2,766 602 (621 ) 11,737 Depreciation, depletion and amortization 537 662 330 30 — 1,559 Impairment of assets and related charges — — — 4 — 4 Gains on sales of assets — 4 (44 ) — — (40 ) Equity in earnings of equity method investees — (16 ) 105 22 — 111 Interest income — 74 34 36 (78 ) 66 Interest and related charges 244 290 38 516 (78 ) 1,010 Income tax expense (benefit) 308 279 431 (363 ) — 655 Net income (loss) attributable to Dominion Energy 484 1,397 726 (484 ) — 2,123 Capital expenditures 1,320 2,440 2,322 43 — 6,125
Virginia Electric and Power Company
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Virginia Power’s operations: Year Ended December 31, Power Delivery Power Generation Corporate and Other Adjustments & Consolidated Total (millions) 2018 Operating revenue $ 2,204 $ 5,630 $ (215 ) $ — $ 7,619 Depreciation and amortization 624 533 (25 ) — 1,132 Interest income — 9 5 (4 ) 10 Interest and related charges 265 250 — (4 ) 511 Income tax expense (benefit) 158 220 (78 ) — 300 Net income (loss) 586 1,008 (312 ) — 1,282 Capital expenditures 1,539 1,003 — — 2,542 Total assets (billions) 17.6 19.4 — (0.1 ) 36.9 2017 Operating revenue $ 2,212 $ 5,344 $ — $ — $ 7,556 Depreciation and amortization 594 547 — — 1,141 Interest income 4 15 3 (3 ) 19 Interest and related charges 265 232 — (3 ) 494 Income tax expense (benefit) 334 534 (94 ) — 774 Net income 527 939 74 — 1,540 Capital expenditures 1,439 1,290 — — 2,729 Total assets (billions) 16.6 18.6 — (0.1 ) 35.1 2016 Operating revenue $ 2,217 $ 5,390 $ (19 ) $ — $ 7,588 Depreciation and amortization 537 488 — — 1,025 Interest income — — — — — Interest and related charges 244 219 — (2 ) 461 Income tax expense (benefit) 307 524 (104 ) — 727 Net income (loss) 482 909 (173 ) — 1,218 Capital expenditures 1,313 1,336 — — 2,649
Dominion Energy Gas Holdings, LLC
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Energy Gas’ operations: Year Ended December 31, Gas Infrastructure Corporate and Other Consolidated Total (millions) 2018 Operating revenue $ 1,940 $ — $ 1,940 Depreciation and amortization 244 — 244 Impairment of assets and related charges 5 341 346 Gains on sales of assets (119 ) — (119 ) Equity in earnings of equity method investees 24 — 24 Interest income 2 — 2 Interest and related charges 104 1 105 Income tax expense (benefit) 188 (102 ) 86 Net income (loss) 552 (251 ) 301 Investment in equity method investees 91 — 91 Capital expenditures 772 — 772 Total assets (billions) 11.8 0.6 12.4 2017 Operating revenue $ 1,814 $ — $ 1,814 Depreciation and amortization 227 — 227 Impairment of assets and related charges 15 1 16 Gains on sales of assets (70 ) — (70 ) Equity in earnings of equity method investees 21 — 21 Interest income 2 — 2 Interest and related charges 97 — 97 Income tax expense (benefit) 256 (205 ) 51 Net income 436 179 615 Investment in equity method investees 95 — 95 Capital expenditures 778 — 778 Total assets (billions) 11.3 0.6 11.9 2016 Operating revenue $ 1,638 $ — $ 1,638 Depreciation and amortization 214 (10 ) 204 Gains on sales of assets (45 ) — (45 ) Equity in earnings of equity method investees 21 — 21 Interest income 1 — 1 Interest and related charges 92 2 94 Income tax expense (benefit) 237 (22 ) 215 Net income (loss) 395 (3 ) 392 Capital expenditures 854 — 854

Quarterly Financial Data (Una_2

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2018
Quarterly Financial Data	A summary of the Companies’ quarterly results of operations for the years ended December 31, 2018 and 2017 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. D OMINION NERGY First Second Third Fourth (millions) 2018 Operating revenue $ 3,466 $ 3,088 $ 3,451 $ 3,361 Income from operations 875 742 1,150 834 Net income including noncontrolling interests 526 478 883 662 Net income attributable to Dominion Energy 503 449 854 641 Basic EPS: Net income attributable to Dominion Energy 0.77 0.69 1.31 0.97 Diluted EPS: Net income attributable to Dominion Energy 0.77 0.69 1.30 0.97 Dividends declared per common share 0.835 0.835 0.835 0.835 2017 Operating revenue $ 3,384 $ 2,813 $ 3,179 $ 3,210 Income from operations 1,079 753 1,152 953 Net income including noncontrolling interests 674 417 696 1,333 Net income attributable to Dominion Energy 632 390 665 1,312 Basic EPS: Net income attributable to Dominion Energy 1.01 0.62 1.03 2.04 Diluted EPS: Net income attributable to Dominion Energy 1.01 0.62 1.03 2.04 Dividends declared per common share 0.755 0.755 0.770 0.770
Virginia Electric and Power Company
Quarterly Financial Data	Virginia Power’s quarterly results of operations were as follows: First Second Third Fourth (millions) 2018 Operating revenue $ 1,748 $ 1,829 $ 2,232 $ 1,810 Income from operations 364 533 756 418 Net income 184 339 520 239 2017 Operating revenue $ 1,831 $ 1,747 $ 2,154 $ 1,824 Income from operations 653 613 847 619 Net income 356 318 459 407
Dominion Energy Gas Holdings, LLC
Quarterly Financial Data	Dominion Energy Gas’ quarterly results of operations were as follows: First Second Third Fourth (millions) 2018 Operating revenue $526 $459 $423 $532 Income (loss) from operations 201 7 182 (55 ) Net income (loss) 166 15 136 (16) 2017 Operating revenue $490 $422 $401 $501 Income from operations 156 116 185 181 Net income 108 77 117 313

Nature of Operations (Narrative

Nature of Operations (Narrative) (Detail)	12 Months Ended
	Dec. 31, 2018Segments
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	3
Iroquois | Partnership Interest | Dominion Energy Midstream Partners, LP
Subsidiary, Sale of Stock [Line Items]
Noncontrolling partnership percentage interest	25.93%
Common and Subordinated Units | Dominion Energy Midstream Partners, LP
Subsidiary, Sale of Stock [Line Items]
Ownership interest percentage of limited partner interests	60.90%
Convertible Preferred Units | Dominion Energy Midstream Partners, LP
Subsidiary, Sale of Stock [Line Items]
Ownership interest percentage of limited partner interests	37.50%
Virginia Electric and Power Company
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	2
Dominion Energy Gas Holdings, LLC
Subsidiary, Sale of Stock [Line Items]
Number of operating segments	1

Significant Accounting Polici_4

Significant Accounting Policies (Narrative) (Detail) $ / shares in Units, $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2018USD ($)Mcfe	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)McfeContract$ / shares	Dec. 31, 2017USD ($)Mcfe	Dec. 31, 2016USD ($)
Significant Accounting Policies [Line Items]
Accrued unbilled revenue	$ 626		$ 626	$ 661
Percentage of fuel currently subject to deferred fuel accounting			84.00%
Federal statutory income tax rate			21.00%	35.00%	35.00%
Recognized interest income			$ 11	$ 11
Margin deposit assets	$ 95		95	92
Capitalized interest costs and AFUDC			134	236	$ 159
Asset impairment charges			$ 403	$ 15	$ 4
Estimated proved developed or proved gas and oil reserves rate per unit | Mcfe	1.89		1.89	2.11
Unrealized gains reclassified from AOCI to retained earnings	$ 1,100		$ 1,100
Unrealized gains reclassified from AOCI to retained earnings after-tax			734
Net unrealized gains on equity securities previously classified as cost method investments	36		36
Net unrealized gains on equity securities previously classified as cost method investments, after tax	22		22
Net unrealized gains in other income			190
Net unrealized gains in other income, after tax			$ 142
Gain per share from unrealized loss on securities | $ / shares			$ 0.22
Tax reform, reclassification of tax benefit from AOCI to retained earnings			$ 289
Accounting Standards Update 2014-09 [Member] | Cumulative Effect Of Changes In Accounting Principle [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interests	3		3
Accounting Standards Update 2017-05 [Member] | Cumulative Effect Of Changes In Accounting Principle [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interests	127		127
Current Regulatory Liabilities [Member]
Significant Accounting Policies [Line Items]
Net unrealized gains on equity securities previously classified as cost method investments	33		33
Retained Earnings
Significant Accounting Policies [Line Items]
Net unrealized gains on equity securities previously classified as cost method investments	3		3
Maximum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	500		$ 500
Maximum | Nonutility Gas Gathering and Processing
Significant Accounting Policies [Line Items]
Estimated useful lives			50 years
Minimum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	450		$ 450
Minimum | Nonutility Gas Gathering and Processing
Significant Accounting Policies [Line Items]
Estimated useful lives			3 years
Change in Depreciation Rates from New Depreciation Study
Significant Accounting Policies [Line Items]
Increase (decrease) in EPS | $ / shares			$ 0.07
Change in Estimated Useful Life | Merchant generation assets
Significant Accounting Policies [Line Items]
Increase (decrease) in depreciation expense			$ (30)	$ 26
Increase (decrease) in depreciation expense, after tax			(23)	16
Performing Processing And Fractionation Services [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Operating revenue			107	0
Other energy-related purchases			107	0
Transportation And Storage Arrangements [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Operating revenue				111
Purchased gas				111
Virginia Electric and Power Company
Significant Accounting Policies [Line Items]
Accrued unbilled revenue	392		$ 392	$ 400
Federal statutory income tax rate			21.00%	35.00%	35.00%
Recognized interest income			$ 11	$ 11
Noncurrent income taxes receivable				1
Margin deposit assets	1		1	23
Capitalized interest costs			56	37	$ 21
AFUDC related to projects			4	22	$ 31
Unrealized gains reclassified from AOCI to retained earnings	119		119
Unrealized gains reclassified from AOCI to retained earnings after-tax			73
Net unrealized gains on equity securities previously classified as cost method investments	36		36
Net unrealized gains on equity securities previously classified as cost method investments, after tax	22		22
Net unrealized gains in other income			24
Net unrealized gains in other income, after tax			18
Tax reform, reclassification of tax benefit from AOCI to retained earnings			3
Virginia Electric and Power Company | Scenario, Forecast
Significant Accounting Policies [Line Items]
Asset impairment charges		$ 190
Asset Impairment Charges After Tax		$ 141
Virginia Electric and Power Company | Current Regulatory Liabilities [Member]
Significant Accounting Policies [Line Items]
Net unrealized gains on equity securities previously classified as cost method investments	33		33
Virginia Electric and Power Company | Retained Earnings
Significant Accounting Policies [Line Items]
Net unrealized gains on equity securities previously classified as cost method investments	3		3
Virginia Electric and Power Company | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	36		36	16
Virginia Electric and Power Company | Change in Depreciation Rates from New Depreciation Study
Significant Accounting Policies [Line Items]
Increase (decrease) in depreciation expense			(60)	40
Increase (decrease) in depreciation expense, after tax			(44)	25
Virginia Electric and Power Company | Federal
Significant Accounting Policies [Line Items]
Noncurrent income taxes receivable				1
Virginia Electric and Power Company | Federal | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	34		34	16
Virginia Electric and Power Company | State | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	2		2
Virginia Electric and Power Company | State | Maximum
Significant Accounting Policies [Line Items]
Noncurrent income taxes receivable				1
Dominion Energy Gas Holdings, LLC
Significant Accounting Policies [Line Items]
Accrued unbilled revenue	131		$ 131	$ 121
Federal statutory income tax rate			21.00%	35.00%	35.00%
Capitalized interest costs			$ 18	$ 25	$ 8
Asset impairment charges	219		346	16
Inventory under LIFO method	12		12	9
Amount exceeded on LIFO basis	87		87	79
Tax reform, reclassification of tax benefit from AOCI to retained earnings			26
Dominion Energy Gas Holdings, LLC | Accounting Standards Update 2014-09 [Member] | Cumulative Effect Of Changes In Accounting Principle [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interests	3		3
Dominion Energy Gas Holdings, LLC | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	2		2	25
Dominion Energy Gas Holdings, LLC | Maximum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	70		$ 70
Dominion Energy Gas Holdings, LLC | Maximum | Nonutility Gas Gathering and Processing
Significant Accounting Policies [Line Items]
Estimated useful lives			50 years
Dominion Energy Gas Holdings, LLC | Minimum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	60		$ 60
Dominion Energy Gas Holdings, LLC | Minimum | Nonutility Gas Gathering and Processing
Significant Accounting Policies [Line Items]
Estimated useful lives			10 years
Dominion Energy Gas Holdings, LLC | Performing Processing And Fractionation Services [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Operating revenue			$ 103	0
Other energy-related purchases			103	0
Dominion Energy Gas Holdings, LLC | Transportation And Storage Arrangements [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Operating revenue				79
Purchased gas				79
Dominion Energy Gas Holdings, LLC | Federal | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	8		8	21
Dominion Energy Gas Holdings, LLC | State
Significant Accounting Policies [Line Items]
Noncurrent income taxes receivable	13		13	14
Dominion Energy Gas Holdings, LLC | State | Affiliated Entity
Significant Accounting Policies [Line Items]
Income tax payable	6		$ 6	$ 4
DETI | Accounting Standards Update 2014-09 [Member] | Cumulative Effect Of Changes In Accounting Principle [Member]
Significant Accounting Policies [Line Items]
Number of existing contracts | Contract			3
Virginia Power [Member] | Maximum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	250		$ 250
Virginia Power [Member] | Minimum
Significant Accounting Policies [Line Items]
Operating lease, right-of-use asset	200		$ 200
SCANA | Maximum
Significant Accounting Policies [Line Items]
Estimated useful lives			78 years
Capital lease obligation non - current	35		$ 35
SCANA | Minimum
Significant Accounting Policies [Line Items]
Estimated useful lives			5 years
Capital lease obligation non - current	$ 30		$ 30
Merchant Solar Projects | Terra Nova Renewable Partners
Significant Accounting Policies [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired	50.00%		50.00%
Percentage of equity interest sold to noncontrolling interest owners	33.00%		33.00%
Merchant Solar Projects | Terra Nova Renewable Partners | Call Option
Significant Accounting Policies [Line Items]
Percentage ownership in total units	67.00%		67.00%

Significant Accounting Polici_5

Significant Accounting Policies (Checks the Outstanding Accounts Payable but not yet Presented for Payment and Recorded) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Accounts Payable [Line Items]
Accounts payable for checks outstanding	$ 35	$ 30
Virginia Electric and Power Company
Accounts Payable [Line Items]
Accounts payable for checks outstanding	16	17
Dominion Energy Gas Holdings, LLC
Accounts Payable [Line Items]
Accounts payable for checks outstanding	$ 7	$ 7

Significant Accounting Polici_6

Significant Accounting Policies (Reconciliation of Total Cash, Restricted Cash and Equivalents) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash, Cash Equivalents and Restricted Cash [Line Items]
Cash and cash equivalents		$ 268	$ 120	$ 261	$ 607
Restricted cash and equivalents	[1]	123	65	61	25
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		391	185	322	632
Virginia Electric and Power Company
Cash, Cash Equivalents and Restricted Cash [Line Items]
Cash and cash equivalents		29	14	11	18
Restricted cash and equivalents	[1]	9	10
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		38	24	11	18
Dominion Energy Gas Holdings, LLC
Cash, Cash Equivalents and Restricted Cash [Line Items]
Cash and cash equivalents		10	4	23	13
Restricted cash and equivalents	[1]	24	26	20	14
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		$ 34	$ 30	$ 43	$ 27
[1]	Restricted cash and equivalent balances are presented within other current assets in the Companies' Consolidated Balance Sheets.

Significant Accounting Polici_7

Significant Accounting Policies (Depreciation Rates and Estimated Useful Life) (Detail)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Merchant Generation Nuclear
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	44 years
LNG Facility [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	40 years
Minimum | Merchant Generation-Other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	15 years
Minimum | Nonutility Gas Gathering and Processing
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Minimum | Nonutility Gas Gathering and Processing | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Minimum | General and Other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Maximum | Merchant Generation-Other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	30 years
Maximum | Nonutility Gas Gathering and Processing
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years
Maximum | Nonutility Gas Gathering and Processing | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years
Maximum | General and Other
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives	59 years
Generation
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.71%	2.94%	2.83%
Generation | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.71%	2.94%	2.83%
Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.54%	2.55%	2.47%
Transmission | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.52%	2.54%	2.36%
Transmission | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.45%	2.40%	2.43%
Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.97%	3.00%	3.02%
Distribution | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	3.31%	3.32%	3.32%
Storage
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.40%	2.48%	2.29%
Storage | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.46%	2.45%	2.19%
Gas Gathering and Processing
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.62%	2.21%	2.66%
Gas Gathering and Processing | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	3.07%	2.42%	2.58%
General and Other
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	4.56%	4.89%	4.12%
General and Other | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	4.52%	4.68%	3.49%
General and Other | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	5.59%	4.96%	4.54%
Distribution | Dominion Energy Gas Holdings, LLC
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.41%	2.42%	2.55%

Acquisitions and Dispositions_2

Acquisitions and Dispositions (Acquisition Of Scana) (Narrative) (Detail) - USD ($) $ / shares in Units, $ in Millions		Sep. 16, 2016	Feb. 28, 2019	Jan. 31, 2019	Aug. 31, 2018	Jul. 31, 2018	Jun. 30, 2018	Oct. 31, 2017	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019	Dec. 31, 2015
Business Acquisition And Dispositions [Line Items]
Regulatory Liabilities										$ 7,196				$ 7,109				$ 7,196	$ 7,109
Regulatory liabilities-current	[1]									356				193				356	193
After tax charge in statements of income										641	$ 854	$ 449	$ 503	1,312	$ 665	$ 390	$ 632	2,447	2,999	$ 2,123
Other Commitment, Fiscal Year Maturity [Abstract]
Cash, restricted cash and equivalents										391				185				391	185	$ 322		$ 632
Deferred tax asset recorded on federal net operating loss carryforwards										1,800								1,800
Deferred tax asset recorded on state net operating loss carryforwards										2,400								2,400
Valuation allowance, deferred tax asset, change in amount																		0
Unrecognized Tax Benefits, Increase Resulting from Acquisition																		106
Property, plant and equipment, in service										$ 76,578				$ 74,823				$ 76,578	$ 74,823
Intangible assets, weighted-average amortization period																		15 years
Preferred stock, shares authorized										20,000,000				20,000,000				20,000,000	20,000,000
Return of equity percentage																				10.50%
Decrease in revenue requirement, natural gas rates																		$ 20
Decrease in revenue requirement, adjustments to customer rates																		13
Before tax charge in statements of income																		3,129	$ 3,090	$ 2,867
Liabilities recorded										$ 55,866				$ 57,215				55,866	$ 57,215
Subsequent Event
Business Acquisition And Dispositions [Line Items]
Stock issued during period for acquisition, shares				22,500,000
Stock issued during period for acquisition, value				$ 1,600
SCE&G [Member] | Subsequent Event
Other Commitment, Fiscal Year Maturity [Abstract]
Preferred stock, shares authorized																					20,000,000
SCANA | Subsequent Event
Other Commitment, Fiscal Year Maturity [Abstract]
Preferred stock, shares authorized			1,000
Preferred stock, no par value			$ 0
SCANA
Business Acquisition And Dispositions [Line Items]
Combination debt outstanding										13,083								$ 13,083
Period to provide refund to customer																		20 years
Regulatory Liabilities								$ 1,100
Refund Liability to electric service customers										1,000								$ 1,000
Business combination cost related to exclusion from rate recovery																		105
Remaining regulatory asset										4,219								4,219
Other Commitment, Fiscal Year Maturity [Abstract]
Charitable contributions, annual committed increase for next five years		$ 1
Cash, restricted cash and equivalents										389								389
Restricted cash										115								115
Equity method investment										20								20
Business combination cost related to exclusion from rate recovery, after tax charge																		79
Property, plant and equipment, in service										16,331								16,331
Regulatory assets for deferred income tax										190								190
Intangible assets										281								281
Intangible assets, accumulated amortization										181								$ 181
Intangible assets, weighted-average amortization period																		5 years
Provision of bill credits impact on retail electric customer rates																		$ 100
Reduction in base rates to retail electric customers																		67
Transaction cost																		27
SCANA | Provision for future cost of removal and AROs
Other Commitment, Fiscal Year Maturity [Abstract]
Purchase price allocation																		577
Business combination, consideration, liabilities incurred																		$ 23
SCANA | Minimum
Other Commitment, Fiscal Year Maturity [Abstract]
Charitable contributions, period committed for annual increase		5 years
Estimated useful lives																		5 years
SCANA | Maximum
Other Commitment, Fiscal Year Maturity [Abstract]
Estimated useful lives																		78 years
SCANA | SCE&G Ratepayer Case [Member]
Other Commitment, Fiscal Year Maturity [Abstract]
Escrow account										$ 2,000								$ 2,000
Credit in future electric rate relief																		2,000
Cash payment																		115
SCANA | SCE&G Ratepayer Case [Member] | Minimum
Other Commitment, Fiscal Year Maturity [Abstract]
Proceeds from sale of property																		60
SCANA | SCE&G Ratepayer Case [Member] | Maximum
Other Commitment, Fiscal Year Maturity [Abstract]
Proceeds from sale of property																		$ 85
SCANA | Scenario, Forecast
Business Acquisition And Dispositions [Line Items]
Period to provide refund to customer									11 years
Regulatory Liabilities									$ 1,000
Reduction in operating revenue									(1,000)
Regulatory liabilities-current									140
After tax charge in statements of income									(756)
Other Commitment, Fiscal Year Maturity [Abstract]
Regulatory assets deferred, expected to be recognized									145
SCANA | Scenario, Forecast | SCE&G Ratepayer Case [Member]
Business Acquisition And Dispositions [Line Items]
After tax charge in statements of income									(135)
Other Commitment, Fiscal Year Maturity [Abstract]
Before tax charge in statements of income									$ (180)
SCANA | Subsequent Event
Business Acquisition And Dispositions [Line Items]
Common stock agreed to issue				66.90%
Stock issued during period for acquisition, shares				95,600,000
Stock issued during period for acquisition, value				$ 6,800
Combination debt outstanding				6,900
Business combination, refund to customers				$ 2,000
Period to provide refund to customer				20 years
Business combination cost related to exclusion from rate recovery				$ 2,400
Remaining regulatory asset				2,800
Other Commitment, Fiscal Year Maturity [Abstract]
Tender offer expire date			Mar. 31, 2019
Repurchase of medium term notes			$ 300
SCANA | Toshiba Corporation
Business Acquisition And Dispositions [Line Items]
Cash consideration								$ 1,100
SCANA | Columbia Energy | Subsequent Event
Business Acquisition And Dispositions [Line Items]
Business combination cost related to exclusion from rate recovery				180
SCANA | V.C. Summer Units
Other Commitment, Fiscal Year Maturity [Abstract]
Equity method investment, ownership percentage										66.70%								66.70%
Property, plant and equipment, in service										$ 1,500								$ 1,500
Property, plant and equipment, accumulated depreciation										644								644
Property, plant and equipment, under construction										$ 128								$ 128
SCE&G [Member]
Other Commitment, Fiscal Year Maturity [Abstract]
Equity method investment, ownership percentage										55.00%								55.00%
Percentage of average residential electric bill						18.00%
Reduction in revenue						$ 31
Liabilities recorded										$ 11								$ 11
Contesting amount for filed liens in Fairfield country					$ 285
Maximum assessment cost,per incident																		92
Maximum yearly assessment per nuclear incident																		14
Maximum amount of coverage to nuclear facility for property damage and outage costs										$ 2,800								2,800
Maximum loss for a single nuclear incident																		2,800
Maximum prosepective insurance premium per nuclear incident																		23
NEIL Maximum Insurance Coverage To Nuclear Facility For Property Damage And Outage Costs From Non-Nuclear Event																		415
Maximum Retrospective Premium Assessment																		$ 2
SCE&G [Member] | SCDOR [Member]
Other Commitment, Fiscal Year Maturity [Abstract]
Proportional share with NND project							100.00%
Proposed assessment amount from audit							$ 410
SCE&G [Member] | SOUTH CAROLINA
Other Commitment, Fiscal Year Maturity [Abstract]
Amount claimed by plaintiffs in legal matter						$ 75
Proportional share with NND project						55.00%
SCE&G [Member] | Subsequent Event
Other Commitment, Fiscal Year Maturity [Abstract]
Repurchase of first mortgage bonds			1,000
Purchase of additional first mortgage bonds			$ (1,200)
Tender offer expire date			Mar. 31, 2019
Recover of cost and net lost revenue with incentive				30
SCE&G [Member] | Subsequent Event | Revolving Credit Facility
Other Commitment, Fiscal Year Maturity [Abstract]
Line of Credit Facility, Maximum Borrowing Capacity				$ 6,000
[1]	Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas' Consolidated Balance Sheets.

Acquisitions and Dispositions_3

Acquisitions and Dispositions (Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Sep. 16, 2016
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Goodwill	[1]	$ 6,410	$ 6,405	$ 6,399
SCANA
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Total current assets		1,756
Investments		213
Property, plant and equipment, net		10,982
Goodwill		2,438
Regulatory assets		4,219
Other deferred charges and other assets, including intangible assets		314
Total Assets		19,922
Total current liabilities		1,506
Long-term debt		6,707
Deferred income taxes		1,097
Regulatory liabilities		2,664
Other deferred credits and other liabilities		1,109
Total Liabilities		13,083
Total purchase price		$ 6,839
Dominion Energy Questar Corporation
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Total current assets					$ 224
Investments	[2]				58
Property, plant and equipment, net	[3]				4,131
Goodwill					3,111
Other deferred charges and other assets, including intangible assets					75
Total Assets					7,599
Total current liabilities	[4]				793
Long-term debt	[5]				963
Deferred income taxes					807
Regulatory liabilities					259
Other deferred credits and other liabilities					220
Total Liabilities					3,202
Total purchase price					4,397
Asset retirement obligations					$ 160
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Includes $40 million for an equity method investment in White River Hub. The fair value adjustment on the equity method investment in White River Hub is considered to be equity method goodwill and is not amortized.
[3]	Nonregulated property, plant and equipment, excluding land, will be depreciated over remaining useful lives primarily ranging from 9 to 18 years
[4]	Includes $301 million of short-term debt, of which no amounts remain outstanding at December 31, 2018, as well as a $250 million variable interest rate term loan due in August 2017 that was paid in July 2017.
[5]	Unsecured senior and medium-term notes with maturities which range from 2017 to 2048 and bear interest at rates from 2.98% to 7.20%.

Acquisitions and Dispositions_4

Acquisitions and Dispositions (Schedule of Property Plant and Equipment) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Utility:
Generation	$ 19,250	$ 17,602
Transmission	16,669	15,335
Distribution	18,549	17,408
Storage	2,905	2,887
Nuclear fuel	1,626	1,599
General and other	1,476	1,514
Plant under construction	2,385	7,765
Total utility	64,930	66,049
Total property, plant and equipment	$ 76,578	$ 74,823
Generation
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.71%	2.94%	2.83%
Transmission
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.54%	2.55%	2.47%
Distribution
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.97%	3.00%	3.02%
Storage
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.40%	2.48%	2.29%
General and Other
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	4.56%	4.89%	4.12%
SCANA
Utility:
Generation	$ 5,720
Transmission	2,416
Distribution	6,044
Storage	99
Nuclear fuel	611
General and other	631
Plant under construction	527
Total utility	16,048
Nonutility, including plant under construction	283
Total property, plant and equipment	$ 16,331
SCANA | Generation
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.61%
SCANA | Transmission
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.47%
SCANA | Distribution
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.48%
SCANA | Storage
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	2.48%
SCANA | General and Other
Utility:
Average composite depreciation rates on utility property, plant and equipment (percentage)	5.64%

Acquisitions and Dispositions_5

Acquisitions and Dispositions (Schedule of Finite-Lived Intangible Assets Future Amortization Expense) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Business Acquisition [Line Items]
2,019	$ 67
2,020	56
2,021	44
2,022	34
2,023	23
SCANA
Business Acquisition [Line Items]
2,019	95
2,020	90
2,021	80
2,022	74
2,023	$ 71

Acquisitions and Dispositions_6

Acquisitions and Dispositions (Schedule of Line of Credit Facilities) (Detail) - USD ($)		Dec. 31, 2018		Dec. 31, 2017
Business Acquisition [Line Items]
Facility Limit		$ 6,000,000,000	[1]	$ 5,500,000,000
Letters of credit advances		88,000,000	[1]	76,000,000
Facility capacity available		5,588,000,000	[1]	$ 2,126,000,000
SCANA Existing Facilities
Business Acquisition [Line Items]
Facility Limit		1,800,000,000
Letters of credit advances		37,000,000
Facility capacity available		1,550,000,000
SCANA Existing Facilities | Letter of Credit
Business Acquisition [Line Items]
Letters of credit advances		$ 40,000,000
Weighted-average interest rate		3.87%
SCANA Existing Facilities | Commercial Paper
Business Acquisition [Line Items]
Weighted-average interest rate		3.63%
Outstanding commercial paper		$ 173,000,000
SCANA Existing Facilities | SCANA
Business Acquisition [Line Items]
Facility Limit		400,000,000
Letters of credit advances		37,000,000
Facility capacity available		321,000,000
SCANA Existing Facilities | SCANA | Letter of Credit
Business Acquisition [Line Items]
Letters of credit advances	[2]	$ 40,000,000
Weighted-average interest rate		3.87%
SCANA Existing Facilities | SCANA | Commercial Paper
Business Acquisition [Line Items]
Weighted-average interest rate		3.65%
Outstanding commercial paper		$ 2,000,000
SCANA Existing Facilities | SCE&G [Member]
Business Acquisition [Line Items]
Facility Limit	[3]	1,200,000,000
Facility capacity available		$ 1,127,000,000
SCANA Existing Facilities | SCE&G [Member] | Commercial Paper
Business Acquisition [Line Items]
Weighted-average interest rate		3.82%
Outstanding commercial paper		$ 73,000,000
SCANA Existing Facilities | PSNC [Member]
Business Acquisition [Line Items]
Facility Limit		200,000,000
Facility capacity available		$ 102,000,000
SCANA Existing Facilities | PSNC [Member] | Commercial Paper
Business Acquisition [Line Items]
Weighted-average interest rate		3.49%
Outstanding commercial paper		$ 98,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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 2019, SCANA repaid $40 million in letter of credit advances.
[3]	Includes South Carolina Fuel Company, Inc.'s $500 million credit facility.

Acquisitions and Dispositions_7

Acquisitions and Dispositions (Schedule of Line of Credit Facilities) (Parenthetical) (Detail) - USD ($)	1 Months Ended
	Jan. 31, 2019	Dec. 31, 2018		Dec. 31, 2017
Business Acquisition [Line Items]
Credit facility amount		$ 6,000,000,000	[1]	$ 5,500,000,000
SCANA | Subsequent Event
Business Acquisition [Line Items]
Repayment of letter of credit advances	$ 40,000,000
South Carolina [Member]
Business Acquisition [Line Items]
Credit facility amount		$ 500,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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.

Acquisitions and Dispositions_8

Acquisitions and Dispositions (Schedule of Long Term Debt) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Business Acquisition [Line Items]
Current maturities of long-term debt	[1],[2]	$ 3,624	$ 3,078
Unamortized discount, premium and debt issuance costs, net		(248)	$ (245)
SCANA
Business Acquisition [Line Items]
Total principal		6,795
Current maturities of long-term debt		(59)
Unamortized discount, premium and debt issuance costs, net		(29)
Total long-term debt		6,707
Variable rate debt		$ 68
Variable rate debt, interest rate		1.72%
SCANA | Unsecured Medium Term Notes due Two Thousand Twenty to Two Thousand Twenty Two [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	5.42%
Total principal		$ 800
SCANA | Unsecured Senior Notes due Two Thousand Nineteen to Two Thousand Thirty Four [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	3.44%
Total principal		$ 70
SCANA | First Mortgage Bonds due Two Thousand Twenty One to Two Thousand Sixty Five [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	5.52%
Total principal		$ 4,990
SCANA | Genco Notes due Two Thousand Nineteen to Two Thousand Twenty Four [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	5.49%
Total principal		$ 40
SCANA | Industrial and Pollution Control Bonds due Two Thousand Twenty Eight to Two Thousand Thirty Eight [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3],[4]	3.52%
Total principal	[4]	$ 122
SCANA | Psnc Senior Debentures and Notes due Two Thousand Twenty to Two Thousand Forty Seven [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	5.07%
Total principal		$ 700
SCANA | Others due Two Thousand Nineteen to Two Thousand Twenty Seven [Member]
Business Acquisition [Line Items]
Weighted- average Coupon (percentage)	[3]	3.46%
Total principal		$ 73
[1]	2017 excludes $250 million of Dominion Energy Questar Pipeline's senior notes that matured in February 2018 using proceeds from the January 2018 issuance, through private placements, of $100 million and $150 million of senior notes that mature in 2028 and 2038, respectively.
[2]	Includes $20 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc.
[3]	Represents weighted-average coupon rates for debt outstanding at closing of the SCANA Combination.
[4]	Includes variable rate debt of $68 million, with a weighted-average interest rate of 1.72%, which is hedged by fixed swaps

Acquisitions and Dispositions_9

Acquisitions and Dispositions (Scheduled Principal Payments of Long-Term Debt) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Weighted- average Coupon, 2019	3.23%
Weighted- average Coupon, 2020	2.80%
Weighted- average Coupon, 2021	3.64%
Weighted- average Coupon, 2022	3.02%
Weighted- average Coupon, 2023	3.41%
Weighted- average Coupon, Thereafter	4.51%
SCANA
Debt Instrument [Line Items]
2,019	$ 59
2,020	368
2,021	797
2,022	266
2,023	14
Thereafter	5,291
Total	$ 6,795
Weighted- average Coupon, 2019	3.91%
Weighted- average Coupon, 2020	6.26%
Weighted- average Coupon, 2021	4.20%
Weighted- average Coupon, 2022	5.22%
Weighted- average Coupon, 2023	3.29%
Weighted- average Coupon, Thereafter	5.51%
Weighted- average Coupon, Total	5.36%
SCANA | Unsecured Senior Notes
Debt Instrument [Line Items]
2,019	$ 4
2,020	4
2,021	4
2,022	4
2,023	4
Thereafter	50
Total	70
SCANA | Unsecured Medium-term Notes [Member]
Debt Instrument [Line Items]
2,020	250
2,021	300
2,022	250
Total	800
SCANA | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
2,021	330
Thereafter	4,660
Total	4,990
SCANA | PSNC Senior Notes And Debentures [Member]
Debt Instrument [Line Items]
2,020	100
2,021	150
Thereafter	450
Total	700
SCANA | Senior Notes
Debt Instrument [Line Items]
2,019	7
2,020	7
2,021	7
2,022	7
2,023	7
Thereafter	5
Total	40
SCANA | Industrial and Pollution Control Bonds [Member]
Debt Instrument [Line Items]
Thereafter	122
Total	122
SCANA | Other Long Term Debt [Member]
Debt Instrument [Line Items]
2,019	48
2,020	7
2,021	6
2,022	5
2,023	3
Thereafter	4
Total	$ 73

Acquisitions and Disposition_10

Acquisitions and Dispositions (Long-term Purchase Commitment) (Detail) - SCANA - Purchased electric capacity $ in Millions	Dec. 31, 2018USD ($)	[1]
Debt Instrument [Line Items]
2,019	$ 31
2,020	30
2,021	30
2,022	30
2,023	30
Thereafter	310
Total	$ 461
[1]	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities which expire at various dates through 2046. Capacity payments under the contracts are generally based on fixed dollar amounts per month.

Acquisitions and Disposition_11

Acquisitions and Dispositions (Lease Commitments) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
2,019	$ 64
2,020	61
2,021	55
2,022	47
2,023	38
Thereafter	384
Total	649
SCANA
Debt Instrument [Line Items]
2,019	10
2,020	8
2,021	7
2,022	6
2,023	4
Thereafter	30
Total	$ 65

Acquisitions and Disposition_12

Acquisitions and Dispositions (Schedule of Unaudited Pro Forma Information) (Detail) - Dominion Energy Questar Corporation - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	[1]	Dec. 31, 2016	[2]
Business Acquisition [Line Items]
Operating Revenue	$ 17,505		$ 12,497
Net income attributable to Dominion Energy	$ 2,081		$ 2,300
Earnings Per Common Share - Basic	$ 2.78		$ 3.73
Earnings Per Common Share - Diluted	$ 2.77		$ 3.73
[1]	Amounts include adjustments for non-recurring costs directly related to the SCANA Combination.
[2]	Amounts include adjustments for non-recurring costs directly related to the Dominion Energy Questar Combination.

Acquisitions and Disposition_13

Acquisitions and Dispositions (Acquisition of Dominion Energy Questar) (Narrative) (Detail) - USD ($) $ / shares in Units, $ in Millions

Dec. 01, 2016

Sep. 16, 2016

Jul. 31, 2017

Dec. 31, 2016

Sep. 30, 2016

Aug. 31, 2016

Apr. 30, 2016

Sep. 30, 2017

Dec. 31, 2016

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Business Acquisition And Dispositions [Line Items]

Issuance of common stock

$ 2,461

$ 1,302

$ 2,152

Issuance of short-term notes

1,450

1,200

Issuance of common stock

2,461

1,302

2,152

Increase (decrease) to goodwill related modifications to preliminary valuation amounts

5

Other Commitment, Fiscal Year Maturity [Abstract]

Repayment of short-term notes

$ 1,450

$ 250

$ 1,800

Dominion Energy Questar Pipeline LLC | Dominion Energy Midstream Partners, LP | Subsidiary of Common Parent | Disposal Group, Disposed of by Sale, Not Discontinued Operations

Other Commitment, Fiscal Year Maturity [Abstract]

Cash consideration

$ 823

Debt financed distribution

300

Amount of consideration

1,300

Dominion Energy Questar Pipeline LLC | Dominion Energy Midstream Partners, LP | Subsidiary of Common Parent | Partnership Interest | Disposal Group, Disposed of by Sale, Not Discontinued Operations

Other Commitment, Fiscal Year Maturity [Abstract]

Combined value of common and convertible preferred units

$ 467

Dominion Energy Questar Pipeline LLC | Dominion Energy Midstream Partners, LP | Limited Partner | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Senior Unsecured Promissory Note Payable | Notes Payable, Other Payables

Other Commitment, Fiscal Year Maturity [Abstract]

Repayments of promissory note

$ 301

Dominion Energy Questar Pipeline LLC | Dominion Energy Midstream Partners, LP | Limited Partner | Common Units | Disposal Group, Disposed of by Sale, Not Discontinued Operations

Other Commitment, Fiscal Year Maturity [Abstract]

Number of common units to be purchased

6,656,839

Questar Fueling Company | Disposal Group, Disposed of by Sale, Not Discontinued Operations

Other Commitment, Fiscal Year Maturity [Abstract]

Cash consideration

$ 28

Underwritten Public Offering

Business Acquisition And Dispositions [Line Items]

Issuance of common stock

$ 756

Term Loans | Dominion Energy Questar Pipeline LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Private Placement Term Loan Agreement Maturing in September 2017

Other Commitment, Fiscal Year Maturity [Abstract]

Repayment of short-term notes

$ 1,200

Capital Unit, Class A

Business Acquisition And Dispositions [Line Items]

Issuance of common stock

$ 1,000

Dominion Energy Questar Corporation

Business Acquisition And Dispositions [Line Items]

Price per share

$ 25

Total consideration

$ 4,400

Number of shares of Dominion Questar outstanding at closing

175,500,000

Issuance of senior notes

$ 1,300

Increase (decrease) to goodwill related modifications to preliminary valuation amounts

$ 6

$ (6)

Contributions to fund Dominion Questar's qualified and non-qualified defined benefit pension plans

$ 75

Dominion Energy Questar Corporation | Commitment for Charitable Contributions

Other Commitment, Fiscal Year Maturity [Abstract]

Charitable contributions, next twelve months

1

Charitable contributions, second year

1

Charitable contributions, third year

1

Charitable contributions, fourth year

1

Charitable contributions, fifth year

$ 1

Dominion Energy Questar Corporation | Commitment for Charitable Contributions | Minimum

Other Commitment, Fiscal Year Maturity [Abstract]

Period for charitable contributions

5 years

Dominion Energy Questar Corporation | White River Hub LLC

Business Acquisition And Dispositions [Line Items]

Ownership percentage

50.00%

Dominion Energy Questar Corporation | Underwritten Public Offering

Business Acquisition And Dispositions [Line Items]

Issuance of common stock

$ 500

Dominion Energy Questar Corporation | Term Loans

Business Acquisition And Dispositions [Line Items]

Issuance of short-term notes

$ 1,200

Dominion Energy Questar Corporation | Capital Unit, Class A

Business Acquisition And Dispositions [Line Items]

Issuance of common stock

$ 1,400

Acquisitions and Disposition_14

Acquisitions and Dispositions (Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed) (Parenthetical) (Detail) - Dominion Energy Questar Corporation - USD ($) $ in Millions	Sep. 16, 2016	Dec. 31, 2018
Business Acquisition [Line Items]
Short-term debt	$ 301
White River Hub LLC
Business Acquisition [Line Items]
Equity method investment	$ 40
Minimum
Business Acquisition [Line Items]
Estimated useful lives	9 years
Maximum
Business Acquisition [Line Items]
Estimated useful lives	18 years
Unsecured Senior Notes | Minimum
Business Acquisition [Line Items]
Interest rate (percentage)		2.98%
Unsecured Senior Notes | Maximum
Business Acquisition [Line Items]
Interest rate (percentage)		7.20%
Variable Interest Rate Short Term Loan Due in August 2017 [Member]
Business Acquisition [Line Items]
Short-term note outstanding	$ 250

Acquisitions and Disposition_15

Acquisitions and Dispositions (Results of Operations and Pro Forma Information) (Narrative) (Detail) - Dominion Energy Questar Corporation - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Increase in operating revenue			$ 379
Increase in net income			73
Other operations and maintenance
Business Acquisition [Line Items]
Transaction and transition costs incurred	$ 9	$ 26	58
Interest And Related Charges
Business Acquisition [Line Items]
Transaction and transition costs incurred			$ 16

Acquisitions and Disposition_16

Acquisitions and Dispositions (Schedule of Acquisitions of Solar Projects) (Detail) $ in Millions		1 Months Ended						12 Months Ended
		Oct. 31, 2017USD ($)ProjectMW	Sep. 30, 2017USD ($)ProjectMW	Jun. 30, 2017USD ($)ProjectMW	May 31, 2017USD ($)ProjectMW	Mar. 31, 2017USD ($)ProjectMW	Feb. 28, 2017USD ($)ProjectMW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Business Acquisition [Line Items]
Project Cost								$ 151	$ 405	$ 40
Community Energy Solar, Inc
Business Acquisition [Line Items]
Number of Projects | Project							1
Total consideration	[1],[2]						$ 29
Project Cost	[3]						$ 205
MW capacity | MW							100
Solar Frontier Americas Holding, LLC
Business Acquisition [Line Items]
Number of Projects | Project	[4]					1
Total consideration	[1],[2]					$ 77
Project Cost	[3]					$ 78
MW capacity | MW						30
Solar Projects from Cypress Creek Renewables, LLC
Business Acquisition [Line Items]
Number of Projects | Project					1
Total consideration	[1],[2]				$ 154
Project Cost	[3]				$ 160
MW capacity | MW					79
Hecate Energy Virginia C&C LLC
Business Acquisition [Line Items]
Number of Projects | Project			1	1
Total consideration	[1],[2]		$ 40	$ 16
Project Cost	[3]		$ 41	$ 16
MW capacity | MW			20	10
Strata Solar Development, LLC/Moorings Farm 2 Holdco, LLC
Business Acquisition [Line Items]
Number of Projects | Project				2
Total consideration	[1],[2]			$ 20
Project Cost	[3]			$ 20
MW capacity | MW				10
Strata Solar Development, LLC
Business Acquisition [Line Items]
Number of Projects | Project		2
Total consideration	[1],[2]	$ 20
Project Cost	[3]	$ 21
MW capacity | MW		10
[1]	Includes $40 million for an equity method investment in White River Hub. The fair value adjustment on the equity method investment in White River Hub is considered to be equity method goodwill and is not amortized.
[2]	The purchase price was primarily allocated to Property, Plant and Equipment.
[3]	Includes acquisition cost.
[4]	In April 2017, Dominion Energy discontinued efforts on the acquisition of the additional 20 MW solar project from Solar Frontier Americas Holding LLC.

Acquisitions and Disposition_17

Acquisitions and Dispositions (Schedule of Acquisitions of Solar Projects) (Parenthetical) (Detail)	1 Months Ended
	Apr. 30, 2017MW
Business Combinations Discontinued Operations And Disposal Groups [Abstract]
Discontinued efforts on acquisition of additional MW capacity	20

Acquisitions and Disposition_18

Acquisitions and Dispositions (Merchant Solar Projects) (Narrative) (Detail) $ in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2015USD ($)Project	Sep. 30, 2015ProjectMW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)ProjectMW	Jan. 31, 2016USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Project Cost			$ 151	$ 405	$ 40
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]
MW capacity | MW		425
Number of solar projects | Project		24
Total number of solar projects related to potential sale | Project	15
Amount of consideration	$ 184					$ 117
Merchant Solar Projects | Disposal Group, Disposed of by Sale, Not Discontinued Operations | SunEdison, Inc
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interest sold to non-controlling interest owners		33.00%
Number of Solar Development Projects in Operation [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired					100.00%
Number of Projects | Project					7
Aggregate purchase price					$ 32
Project Cost					$ 421
MW capacity | MW					221

Acquisitions and Disposition_19

Acquisitions and Dispositions (Narrative) (Detail) $ in Millions	1 Months Ended		3 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)Project	Jun. 30, 2015USD ($)ProjectMW	Sep. 30, 2016USD ($)MW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Nov. 30, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Project Cost				$ 151	$ 405	$ 40
Four Brothers Solar, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired		50.00%
Number of Projects | Project		4
Purchase price		$ 64
MW capacity | MW		320
Project Cost			$ 670
Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired	50.00%
Number of Projects | Project	3
Purchase price	$ 43
MW capacity | MW			210
Project Cost			$ 450
Four Brothers and Three Cedars | Investment Credits | IRS
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of federal investment tax credits on projects claimed				99.00%
NRG Energy, Inc
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions from SunEdison and NRG to Four Brothers and Three Cedars					9
NRG Energy, Inc | Four Brothers and Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interests acquired							50.00%
Sun Edison Inc
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions from SunEdison and NRG to Four Brothers and Three Cedars						$ 189
Sun Edison Inc | Four Brothers and Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions from SunEdison and NRG to Four Brothers and Three Cedars					$ 301

Operating Revenue (Schedule of

Operating Revenue (Schedule of Operating Revenue Recognition from Contracts with Customers) (Detail) - USD ($) $ in Millions

3 Months Ended

12 Months Ended

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2018

Dec. 31, 2017

Dec. 31, 2016

Public Utilities General Disclosures [Line Items]

Operating revenue

$ 3,361

$ 3,451

$ 3,088

$ 3,466

$ 3,210

$ 3,179

$ 2,813

$ 3,384

$ 13,366

[1]

$ 12,586

[1]

$ 11,737

[1]

Virginia Electric and Power Company

Public Utilities General Disclosures [Line Items]

Operating revenue

1,810

2,232

1,829

1,748

1,824

2,154

1,747

1,831

7,619

[2]

7,556

[2]

7,588

[2]

Dominion Energy Gas Holdings, LLC

Public Utilities General Disclosures [Line Items]

Operating revenue

$ 532

$ 423

$ 459

$ 526

$ 501

$ 401

$ 422

$ 490

1,940

[3]

$ 1,814

[3]

$ 1,638

[3]

Subsequent To Adoption of Revised Guidance

Public Utilities General Disclosures [Line Items]

Operating revenue

12,895

Nonregulated electric sales

1,294

Nonregulated gas sales

214

Nonregulated gas transportation and storage

442

Other regulated revenues

179

Other nonregulated revenues

[4],[5]

563

Operating revenue

13,366

Subsequent To Adoption of Revised Guidance | FERC-regulated

Public Utilities General Disclosures [Line Items]

Regulated gas transportation and storage

1,091

Subsequent To Adoption of Revised Guidance | State-regulated

Public Utilities General Disclosures [Line Items]

Regulated gas transportation and storage

640

Subsequent To Adoption of Revised Guidance | Residential

Public Utilities General Disclosures [Line Items]

Regulated gas sales

818

Subsequent To Adoption of Revised Guidance | Commercial

Public Utilities General Disclosures [Line Items]

Regulated gas sales

221

Subsequent To Adoption of Revised Guidance | Other

Public Utilities General Disclosures [Line Items]

Regulated gas sales

36

Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Residential

Public Utilities General Disclosures [Line Items]

Operating revenue

3,413

Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Commercial

Public Utilities General Disclosures [Line Items]

Operating revenue

2,503

Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Industrial

Public Utilities General Disclosures [Line Items]

Operating revenue

490

Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Government and Other Retail

Public Utilities General Disclosures [Line Items]

Operating revenue

854

Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Wholesale

Public Utilities General Disclosures [Line Items]

Operating revenue

137

Subsequent To Adoption of Revised Guidance | Other

Public Utilities General Disclosures [Line Items]

Operating revenue

[4],[6]

471

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company

Public Utilities General Disclosures [Line Items]

Operating revenue

7,584

Other regulated revenues

132

Other nonregulated revenues

[4],[5]

55

Operating revenue

7,619

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Regulated Electric Sales | Residential

Public Utilities General Disclosures [Line Items]

Operating revenue

3,413

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Regulated Electric Sales | Commercial

Public Utilities General Disclosures [Line Items]

Operating revenue

2,503

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Regulated Electric Sales | Industrial

Public Utilities General Disclosures [Line Items]

Operating revenue

490

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Regulated Electric Sales | Government and Other Retail

Public Utilities General Disclosures [Line Items]

Operating revenue

854

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Regulated Electric Sales | Wholesale

Public Utilities General Disclosures [Line Items]

Operating revenue

137

Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company | Other

Public Utilities General Disclosures [Line Items]

Operating revenue

[5],[6]

35

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC

Public Utilities General Disclosures [Line Items]

Operating revenue

1,949

Nonregulated gas sales

[5]

13

Other regulated revenues

[5]

22

Other nonregulated revenues

[5]

10

Operating revenue

1,940

Management service revenue

[5]

205

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | FERC-regulated

Public Utilities General Disclosures [Line Items]

Regulated gas transportation and storage

[5]

763

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | State-regulated

Public Utilities General Disclosures [Line Items]

Regulated gas transportation and storage

[5]

605

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | Residential

Public Utilities General Disclosures [Line Items]

Regulated gas sales

81

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | Other

Public Utilities General Disclosures [Line Items]

Regulated gas sales

27

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | Other

Public Utilities General Disclosures [Line Items]

Operating revenue

(9)

Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | NGL Production

Public Utilities General Disclosures [Line Items]

Operating revenue

[4],[5]

$ 223

[1]

See Note 9 for amounts attributable to related parties.

[2]

See Note 24 for amounts attributable to affiliates.

[3]

See Note 24 for amounts attributable to related parties.

[4]

Amounts above include $241 million and $206 million for the year ended December 31, 2018 primarily consisting of NGL sales at Dominion Energy and Dominion Energy Gas, respectively, which are considered to be goods transferred at a point in time. In addition, the amounts include $17 million and $11 million of sales of renewable energy credits at both Dominion Energy and Virginia Power for the year ended December 31, 2018, respectively, which are considered to be goods transferred at a point in time.

[5]

See Notes 9 and 24 for amounts attributable to related parties and affiliates.

[6]

Amounts above include $15 million of alternative revenue at Dominion Energy and Virginia Power for the year ended December 31, 2018.

Operating Revenue (Schedule o_2

Operating Revenue (Schedule of Operating Revenue Recognition from Contracts with Customers) (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Public Utilities General Disclosures [Line Items]
Alternative revenue	$ 15
NGL Midstream
Public Utilities General Disclosures [Line Items]
Sales revenue	241
Renewable Energy Investment Tax Credits
Public Utilities General Disclosures [Line Items]
Sales revenue	17
Virginia Electric and Power Company | Renewable Energy Investment Tax Credits
Public Utilities General Disclosures [Line Items]
Sales revenue	11
Dominion Energy Gas Holdings, LLC | NGL Midstream
Public Utilities General Disclosures [Line Items]
Sales revenue	$ 206

Operating Revenue (Schedule o_3

Operating Revenue (Schedule of Aggregate Amount of Transaction Price Allocated To Fixed-price Performance Obligations That Unsatisfied At End of Reporting Period And Expected To be Recognized) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2019-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,643
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2019-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 21
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2019-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 600
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2020-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,563
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2020-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 3
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2020-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 560
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,448
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 475
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,319
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 0
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 384
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,154
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 0
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 268
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 13,693
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01 | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 0
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01 | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 1,612
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil) [Member]
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 20,820
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil) [Member] | Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	25
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil) [Member] | Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 3,899

Operative Revenue (Narrative) (

Operative Revenue (Narrative) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Revenues From Contract With Customer [Line Items]
Contract asset balances	$ 42	$ 46
Contract liability balances	106	132
Revenue recognized from contract liability balances	94
Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Contract asset balances	58	66
Contract liability balances	40	41
Revenue recognized from contract liability balances	41
Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Contract liability balances	22	$ 50
Revenue recognized from contract liability balances	$ 25

Operating Revenue (Schedule o_4

Operating Revenue (Schedule of Operating Revenue Prior to Revised Guidance of Revenue Recognition From Contracts with Customers ) (Detail) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Public Utilities General Disclosures [Line Items]
Total operating revenue	$ 3,361	$ 3,451	$ 3,088	$ 3,466	$ 3,210	$ 3,179	$ 2,813	$ 3,384	$ 13,366	[1]	$ 12,586	[1]	$ 11,737	[1]
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total operating revenue	1,810	2,232	1,829	1,748	1,824	2,154	1,747	1,831	7,619	[2]	7,556	[2]	7,588	[2]
Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Total operating revenue	$ 532	$ 423	$ 459	$ 526	$ 501	$ 401	$ 422	$ 490	$ 1,940	[3]	1,814	[3]	1,638	[3]
Prior to adoption of revised guidance
Public Utilities General Disclosures [Line Items]
Nonregulated electric sales											1,429		1,519
Regulated gas sales											1,067		500
Nonregulated gas sales											457		354
Total operating revenue											12,586		11,737
Prior to adoption of revised guidance | Regulated Electric Sales
Public Utilities General Disclosures [Line Items]
Revenue											7,383		7,348
Prior to adoption of revised guidance | Gas Transportation and Storage
Public Utilities General Disclosures [Line Items]
Revenue											1,786		1,636
Prior to adoption of revised guidance | Other
Public Utilities General Disclosures [Line Items]
Revenue											464		380
Prior to adoption of revised guidance | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total operating revenue											7,556		7,588
Prior to adoption of revised guidance | Virginia Electric and Power Company | Regulated Electric Sales
Public Utilities General Disclosures [Line Items]
Revenue											7,383		7,348
Prior to adoption of revised guidance | Virginia Electric and Power Company | Other
Public Utilities General Disclosures [Line Items]
Revenue											173		240
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Regulated gas sales											87		119
Nonregulated gas sales											20		13
Total operating revenue											1,814		1,638
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC | Gas Transportation and Storage
Public Utilities General Disclosures [Line Items]
Revenue											1,435		1,307
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC | Other
Public Utilities General Disclosures [Line Items]
Revenue											181		137
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC | NGL Production
Public Utilities General Disclosures [Line Items]
Revenue											$ 91		$ 62
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Detail) - USD ($) $ in Millions	1 Months Ended		3 Months Ended	12 Months Ended
	Oct. 31, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Taxes [Line Items]
Federal statutory income tax rate				21.00%	35.00%	35.00%
State deferred income tax expense				$ (1)	$ 132	$ 50
Current federal income taxes				63	(27)	(70)
Deferred income tax expense			$ (851)	46	(851)	0
Benefit for deferred income taxes						96
Increase (Decrease) to deferred income tax expense				23
Increase (Decrease) in regulatory liabilities				35	4,200
Decrease in unrecognized tax benefits due to settlement				6	23	8
Unrecognized tax benefits that would impact effective tax rate			31	37	31	45
Decrease in accumulated deferred income tax liability			3,100		3,100
Increase in deferred tax asset					1,100
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits				(5)	$ (9)	(18)
Carryback claim for specified liability losses involving prior tax years
Income Taxes [Line Items]
Current federal income taxes				(47)
Maximum
Income Taxes [Line Items]
State deferred income tax expense				1
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations				18
Amount that earnings could potentially increase if changes were to occur				$ 17
Federal
Income Taxes [Line Items]
Federal tax credits						129
Realizable domestic production activities deduction						17
Federal | Dominion Midstream Partners, LP | Questar Pipeline, LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Taxes [Line Items]
Current federal income taxes						$ 212
Virginia Electric and Power Company
Income Taxes [Line Items]
Federal statutory income tax rate				21.00%	35.00%	35.00%
State deferred income tax expense				$ 55	$ 59	$ 27
Current federal income taxes				76	505	258
Deferred income tax expense			(93)	21	(93)	0
Increase (Decrease) to deferred income tax expense				23
Increase (Decrease) in regulatory liabilities	$ 14			31	2,600
Decrease in unrecognized tax benefits due to settlement		$ 8		1	8
Unrecognized tax benefits that would impact effective tax rate		2	3	2	3	9
Interest income		$ 11
Decrease in accumulated deferred income tax liability			1,900		1,900
Increase in deferred tax asset					700
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits				$ (2)	$ (6)	$ 1
Dominion Energy Gas Holdings, LLC
Income Taxes [Line Items]
Federal statutory income tax rate				21.00%	35.00%	35.00%
State deferred income tax expense				$ (4)	$ 20	$ 1
Current federal income taxes				53	24	(23)
Deferred income tax expense			(197)	(11)	(197)	0
Increase (Decrease) to deferred income tax expense				11
Increase (Decrease) in regulatory liabilities				(16)	1,000
Decrease in unrecognized tax benefits due to settlement					7	4
Unrecognized tax benefits that would impact effective tax rate						5
Decrease in accumulated deferred income tax liability			800		800
Increase in deferred tax asset					200
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits				(1)	(5)	$ (11)
Dominion Energy Gas Holdings, LLC | Maximum
Income Taxes [Line Items]
Unrecognized tax benefits that would impact effective tax rate			$ 1	1	$ 1
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations				1
Amount that earnings could potentially increase if changes were to occur				$ 1

Income Taxes (Income Tax Expens

Income Taxes (Income Tax Expense for Continuing Operations Including Noncontrolling Interests) (Detail) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current:
Federal		$ (45)	$ (1)	$ (155)
State		108	(26)	85
Total current expense (benefit)		63	(27)	(70)
Deferred:
2017 Tax Reform Act impact	$ (851)	46	(851)	0
Taxes before operating loss carryforwards and investment tax credits		436	739	1,050
Tax utilization expense (benefit) of operating loss carryforwards		92	174	(161)
Investment tax credits		(56)	(200)	(248)
State		(1)	132	50
Total deferred expense (benefit)		517	(6)	691
Investment tax credit-gross deferral		2	5	35
Investment tax credit-amortization		(2)	(2)	(1)
Total income tax expense (benefit)		580	(30)	655
Virginia Electric and Power Company
Current:
Federal		36	432	168
State		40	73	90
Total current expense (benefit)		76	505	258
Deferred:
2017 Tax Reform Act impact	(93)	21	(93)	0
Taxes before operating loss carryforwards and investment tax credits		199	319	435
Tax utilization expense (benefit) of operating loss carryforwards		0	4	(2)
Investment tax credits		(51)	(23)	(25)
State		55	59	27
Total deferred expense (benefit)		224	266	435
Investment tax credit-gross deferral		2	5	35
Investment tax credit-amortization		(2)	(2)	(1)
Total income tax expense (benefit)		300	774	727
Dominion Energy Gas Holdings, LLC
Current:
Federal		23	16	(27)
State		30	8	4
Total current expense (benefit)		53	24	(23)
Deferred:
2017 Tax Reform Act impact	$ (197)	(11)	(197)	0
Taxes before operating loss carryforwards and investment tax credits		48	199	239
Tax utilization expense (benefit) of operating loss carryforwards		0	5	(2)
Investment tax credits		0	0	0
State		(4)	20	1
Total deferred expense (benefit)		33	27	238
Investment tax credit-gross deferral		0	0	0
Investment tax credit-amortization		0	0	0
Total income tax expense (benefit)		$ 86	$ 51	$ 215

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Income Taxes at the U.S. Statutory Federal Income Tax Rate) (Detail)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.00%	2.00%	2.40%
Investment tax credits	(1.90%)	(6.30%)	(11.70%)
Production tax credits	(0.70%)	(0.70%)	(0.80%)
Valuation allowances	0.30%	0.20%	1.20%
Reversal of excess deferred income taxes	(2.00%)
Federal legislative change	1.50%	(27.50%)
State legislative change	(0.60%)		(0.60%)
AFUDC-equity	(0.80%)	(1.40%)	(0.60%)
Employee stock ownership plan deduction	(0.40%)	(0.60%)	(0.60%)
Other, net	(0.90%)	(1.70%)	(1.40%)
Effective tax rate	18.50%	(1.00%)	22.90%
Virginia Electric and Power Company
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.70%	3.70%	3.80%
Investment tax credits	(3.50%)	(0.80%)
Production tax credits	(0.70%)	(0.40%)	(0.50%)
Valuation allowances			0.10%
Reversal of excess deferred income taxes	(3.20%)
Federal legislative change	1.30%	(4.00%)
AFUDC-equity	(0.50%)	(0.60%)	(0.60%)
Other, net	(0.10%)	0.60%	(0.40%)
Effective tax rate	19.00%	33.50%	37.40%
Dominion Energy Gas Holdings, LLC
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.20%	2.40%	0.50%
Valuation allowances	1.80%	0.30%
Reversal of excess deferred income taxes	(1.70%)
Federal legislative change	(2.80%)	(29.50%)
State legislative change	0.20%
AFUDC-equity	(0.60%)	(0.90%)	(0.20%)
Other, net	1.20%	0.40%	0.10%
Effective tax rate	22.30%	7.70%	35.40%

Income Taxes (Schedule of Defer

Income Taxes (Schedule of Deferred Income Taxes) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Deferred income taxes:
Total deferred income tax assets	$ 2,748	$ 2,686
Total deferred income tax liabilities	7,813	7,158
Total net deferred income tax liabilities	5,065	4,472
Plant and equipment, primarily depreciation method and basis differences	4,933	5,056
Excess deferred income taxes	(993)	(1,050)
Nuclear decommissioning	815	829
Deferred state income taxes	626	834
Federal benefit of deferred state income taxes	(132)	(175)
Deferred fuel, purchased energy and gas costs	60	1
Pension benefits	81	141
Other postretirement benefits	(5)	(51)
Loss and credit carryforwards	(1,546)	(1,536)
Valuation allowances	158	146
Partnership basis differences	1,135	473
Other	(67)	(196)
Total net deferred income tax liabilities	5,065	4,472
Deferred Investment Tax Credits - Regulated Operations	51	51
Total Deferred Taxes and Deferred Investment Tax Credits	5,116	4,523
Virginia Electric and Power Company
Deferred income taxes:
Total deferred income tax assets	1,054	923
Total deferred income tax liabilities	4,020	3,600
Total net deferred income tax liabilities	2,966	2,677
Plant and equipment, primarily depreciation method and basis differences	3,367	2,969
Excess deferred income taxes	(678)	(687)
Nuclear decommissioning	273	260
Deferred state income taxes	284	378
Federal benefit of deferred state income taxes	(60)	(79)
Deferred fuel, purchased energy and gas costs	59	(3)
Pension benefits	(132)	(104)
Other postretirement benefits	55	44
Loss and credit carryforwards	(183)	(111)
Valuation allowances	5	5
Other	(24)	5
Total net deferred income tax liabilities	2,966	2,677
Deferred Investment Tax Credits - Regulated Operations	51	51
Total Deferred Taxes and Deferred Investment Tax Credits	3,017	2,728
Dominion Energy Gas Holdings, LLC
Deferred income taxes:
Total deferred income tax assets	318	320
Total deferred income tax liabilities	1,783	1,774
Total net deferred income tax liabilities	1,465	1,454
Plant and equipment, primarily depreciation method and basis differences	1,170	1,132
Excess deferred income taxes	(254)	(244)
Deferred state income taxes	175	227
Federal benefit of deferred state income taxes	(37)	(48)
Deferred fuel, purchased energy and gas costs	1	2
Pension benefits	431	419
Other postretirement benefits	(1)	(2)
Loss and credit carryforwards	(7)	(4)
Valuation allowances	12	3
Partnership basis differences	26	26
Other	(51)	(57)
Total net deferred income tax liabilities	1,465	1,454
Total Deferred Taxes and Deferred Investment Tax Credits	$ 1,465	$ 1,454

Income Taxes (Schedule of Deduc

Income Taxes (Schedule of Deductible Loss and Credit Carryforwards) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Deductible loss and credit carryforwards [Line Items]
Deductible amount	$ 1,246
Deferred Tax Asset	1,546
Valuation Allowance	(151)
Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Deductible amount	1
Deferred Tax Asset	183
Valuation Allowance	(5)
Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Deductible amount	53
Deferred Tax Asset	6
Valuation Allowance	(5)
Federal
Deductible loss and credit carryforwards [Line Items]
Deductible amount	120
Losses, Deferred tax asset	25
Losses, Valuation allowance	0
Tax credits, Deferred tax asset	62
Federal | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Deductible amount	$ 1
Losses, Expiration Period	2,034
Federal | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deductible amount	$ 0
Tax credits, Deferred tax asset	1
Tax Credits, Valuation allowance	0
Federal | Investment Credits
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	1,007
Federal | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	113
Federal | Federal production credits
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	150
Federal | Federal Production And Other Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	61
State
Deductible loss and credit carryforwards [Line Items]
Deductible amount	1,126
Losses, Deferred tax asset	73
Losses, Valuation allowance	(61)
State minimum tax credits	122
State | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Deductible amount	53
Losses, Deferred tax asset	5
Losses, Valuation allowance	(5)
State | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	9
Tax Credits, Valuation allowance	(5)
State | Investment and Other Credit
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	107
Tax Credits, Valuation allowance	$ (90)
Earliest Tax Year | Federal
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,031
Earliest Tax Year | Federal | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,032
Earliest Tax Year | Federal | Investment Credits
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,033
Earliest Tax Year | Federal | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,034
Earliest Tax Year | Federal | Federal production credits
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,031
Earliest Tax Year | Federal | Federal Production And Other Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,031
Earliest Tax Year | State
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2,019
Earliest Tax Year | State | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2,036
Earliest Tax Year | State | Investment and Other Credit
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,019
Latest Tax Year | Federal
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2,034
Tax Credits, Expiration Period	2,038
Latest Tax Year | Federal | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,037
Latest Tax Year | Federal | Investment Credits
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,038
Latest Tax Year | Federal | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,038
Latest Tax Year | Federal | Federal production credits
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,038
Latest Tax Year | Federal | Federal Production And Other Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,038
Latest Tax Year | State
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2,038
Latest Tax Year | State | Dominion Energy Gas Holdings, LLC
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2,038
Latest Tax Year | State | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,024
Latest Tax Year | State | Investment and Other Credit
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2,025

Income Taxes (Unrecognized Tax

Income Taxes (Unrecognized Tax Benefits) (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1		$ 38	$ 64	$ 103
Increases-prior period positions		10	1	9
Decreases-prior period positions			(9)	(44)
Increases-current period positions		10	5	6
Settlements with tax authorities		(6)	(23)	(8)
Expiration of statutes of limitations		(8)		(2)
Balance at December 31		44	38	64
Virginia Electric and Power Company
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1		4	13	12
Increases-prior period positions				4
Decreases-prior period positions			(1)	(3)
Settlements with tax authorities	$ (8)	(1)	(8)
Expiration of statutes of limitations		(1)
Balance at December 31		$ 2	4	13
Dominion Energy Gas Holdings, LLC
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1			7	29
Increases-prior period positions				1
Decreases-prior period positions				(19)
Settlements with tax authorities			$ (7)	(4)
Balance at December 31				$ 7

Income Taxes (Earliest Tax Year

Income Taxes (Earliest Tax Year) (Detail)	12 Months Ended
	Dec. 31, 2018
Pennsylvania
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,012	[1]
Connecticut
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,015
Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,015	[2]
West Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,015	[1]
New York
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,011	[1]
Utah
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2,015
[1]	Considered a major state for Dominion Energy Gas' operations.
[2]	Considered a major state for Virginia Power's operations.

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Detail) $ in Millions		12 Months Ended
		Dec. 31, 2018USD ($)$ / MWh$ / DTH	Dec. 31, 2017USD ($)$ / MWh$ / DTH	Dec. 31, 2016$ / MWh$ / DTH
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 294	$ 307
Fair Value of Derivative Liabilities		279	284
Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		93	166
Fair Value of Derivative Liabilities		103	66
Fair Value, Measurements, Recurring
Fair Value, Option, Quantitative Disclosures [Line Items]
Total Assets		5,156	5,379
Total liabilities		279	284
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total Assets		2,297	2,466
Total liabilities		103	66
Fair Value, Measurements, Recurring | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		250	258
Fair Value of Derivative Liabilities		135	197
Fair Value, Measurements, Recurring | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		90	166
Fair Value of Derivative Liabilities		15	9
Fair Value, Measurements, Recurring | Level 3
Fair Value, Option, Quantitative Disclosures [Line Items]
Total Assets		70	157
Total liabilities		6	7
Fair Value, Measurements, Recurring | Level 3 | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total Assets		66	152
Total liabilities		6	5
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		70	157
Fair Value of Derivative Liabilities		6	7
Fair Value, Measurements, Recurring | Level 3 | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		66	152
Fair Value of Derivative Liabilities		6	$ 5
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		15
Fair Value of Derivative Liabilities		6
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		15
Fair Value of Derivative Liabilities		$ 6
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity | Liabilities | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity | Liabilities | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity | Liabilities | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		6
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | FTRs [Member] | Commodity | Liabilities | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh			6
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		7
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh			7
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[1]	1
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Assets | FTRs [Member] | Commodity | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh				1
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[2]	$ 42
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[2],[3]	$ 38
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH	[4]	(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH		(2)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH	[4]	8
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH			8
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH	[1],[4]	(1)
Fair Value, Measurements, Recurring | Discounted Cash Flow [Member] | Level 3 | Natural Gas | Assets | Commodity | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH				(1)
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Electricity | Physical Options [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 11
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Electricity | Physical Options [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 11
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		(34)
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		34
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh		50
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh			50
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[1]	42
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Market Price [Member] | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh				42
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		(39.00%)
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		39.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		60.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)			60.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[1]	49.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Assets | Electricity | Physical Options [Member] | Price Volatility [Member] | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)				49.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Physical Options [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 2
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Physical Options [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 2
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH		1
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH		1
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH		8
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH			8
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH	[1]	3
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Market Price [Member] | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / DTH				3
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		18.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Minimum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		18.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)		73.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Maximum | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)			73.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Weighted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[1]	30.00%
Fair Value, Measurements, Recurring | Option Model [Member] | Level 3 | Natural Gas | Assets | Physical Options [Member] | Price Volatility [Member] | Weighted Average | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)				30.00%
[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.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Detail) - USD ($)	3 Months Ended		12 Months Ended
	Dec. 31, 2018		Dec. 31, 2018		Dec. 31, 2017	Dec. 31, 2016	Oct. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Facility Limit	$ 6,000,000,000	[1]	$ 6,000,000,000	[1]	$ 5,500,000,000
Asset impairment charges			403,000,000		15,000,000	$ 4,000,000
Revolving Credit Facility | Atlantic Coast Pipeline | Financial Guarantee [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Facility Limit							$ 3,400,000,000
Guarantee liability							$ 30,000,000
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Facility Limit	6,000,000,000	[2]	6,000,000,000	[2]	5,500,000,000
Unrealized gains and losses included in earnings in Level 3 fair value category			0		0	0
Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Facility Limit	1,500,000,000	[3]	1,500,000,000	[3]	1,500,000,000
Asset impairment charges	219,000,000		346,000,000		16,000,000
Asset impairment charges, after tax	165,000,000
Property, plant and equipment estimated fair value	$ 190,000,000		190,000,000
Unrealized gains and losses included in earnings in Level 3 fair value category			$ 0		$ 0	$ 0
[1]	This credit facility matures in March 2023 and can be used by the Companies 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 full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Virginia Power was $1.5 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 Energy. This credit facility matures in March 2023 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.
[3]	A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy 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 Energy. This credit facility matures in March 2023 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.

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		$ 294	$ 307
Derivative Liabilities		279	284
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		93	166
Derivative Liabilities		103	66
Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		29	32	[1]
Derivative Liabilities		19	8
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		5,156	5,379
Total liabilities		279	284
Fair Value, Measurements, Recurring | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	3,277	3,493
Fair Value, Measurements, Recurring | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		431	444
Fair Value, Measurements, Recurring | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		1,143	1,101
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		11	34
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		250	258
Derivative Liabilities		135	197
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		18	17
Derivative Liabilities		142	85
Fair Value, Measurements, Recurring | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		26	32
Derivative Liabilities		2	2
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		2,297	2,466
Total liabilities		103	66
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	3	1,566
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	1,476	224
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	221	494
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	507	16
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		90	166
Derivative Liabilities		15	9
Fair Value, Measurements, Recurring | Virginia Electric and Power Company | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		88	57
Fair Value, Measurements, Recurring | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		29	32
Total liabilities		19	8
Fair Value, Measurements, Recurring | Dominion Energy Gas Holdings, LLC | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		3
Derivative Liabilities			6
Fair Value, Measurements, Recurring | Dominion Energy Gas Holdings, LLC | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		17
Fair Value, Measurements, Recurring | Dominion Energy Gas Holdings, LLC | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		26	32
Derivative Liabilities		2	2
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		3,743	3,834
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	3,277	3,493
Fair Value, Measurements, Recurring | Level 1 | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		455	307
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		11	34
Fair Value, Measurements, Recurring | Level 1 | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		1,640	1,750
Fair Value, Measurements, Recurring | Level 1 | Virginia Electric and Power Company | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		1,566
Fair Value, Measurements, Recurring | Level 1 | Virginia Electric and Power Company | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	1,476
Fair Value, Measurements, Recurring | Level 1 | Virginia Electric and Power Company | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		168
Fair Value, Measurements, Recurring | Level 1 | Virginia Electric and Power Company | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	164	16
Fair Value, Measurements, Recurring | Level 1 | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		0	0
Total liabilities		0	0
Fair Value, Measurements, Recurring | Level 1 | Dominion Energy Gas Holdings, LLC | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0
Derivative Liabilities			0
Fair Value, Measurements, Recurring | Level 1 | Dominion Energy Gas Holdings, LLC | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		0
Fair Value, Measurements, Recurring | Level 1 | Dominion Energy Gas Holdings, LLC | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		0	0
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		1,343	1,388
Total liabilities		273	277
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		431	444
Fair Value, Measurements, Recurring | Level 2 | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments		688	794
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		180	101
Derivative Liabilities		129	190
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		18	17
Derivative Liabilities		142	85
Fair Value, Measurements, Recurring | Level 2 | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		26	32
Derivative Liabilities		2	2
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		591	564
Total liabilities		97	61
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	3
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		224
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	221	326
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	343
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		24	14
Derivative Liabilities		9	4
Fair Value, Measurements, Recurring | Level 2 | Virginia Electric and Power Company | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		88	57
Fair Value, Measurements, Recurring | Level 2 | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		29	32
Total liabilities		19	6
Fair Value, Measurements, Recurring | Level 2 | Dominion Energy Gas Holdings, LLC | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		3
Derivative Liabilities			4
Fair Value, Measurements, Recurring | Level 2 | Dominion Energy Gas Holdings, LLC | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		17
Fair Value, Measurements, Recurring | Level 2 | Dominion Energy Gas Holdings, LLC | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		26	32
Derivative Liabilities		2	2
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		70	157
Total liabilities		6	7
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		70	157
Derivative Liabilities		6	7
Fair Value, Measurements, Recurring | Level 3 | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		66	152
Total liabilities		6	5
Fair Value, Measurements, Recurring | Level 3 | Virginia Electric and Power Company | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		66	152
Derivative Liabilities		6	5
Fair Value, Measurements, Recurring | Level 3 | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		0	0
Total liabilities		0	2
Fair Value, Measurements, Recurring | Level 3 | Dominion Energy Gas Holdings, LLC | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0
Derivative Liabilities			2
Fair Value, Measurements, Recurring | Level 3 | Dominion Energy Gas Holdings, LLC | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		0
Fair Value, Measurements, Recurring | Level 3 | Dominion Energy Gas Holdings, LLC | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		$ 0	$ 0
[1]	Current derivative liabilities are presented in other current liabilities in Virginia Power's Consolidated Balance Sheets.
[2]	Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $220 million and $88 million of assets at December 31, 2018 and 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.

Fair Value Measurements (Asse_2

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets measured at fair value using NAV	$ 220	$ 88
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets measured at fair value using NAV	$ 160	$ 27

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) (Detail) - Commodity - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 150	$ 139	$ 95
Total realized and unrealized gains (losses):
Included in other comprehensive income (loss)	1	(2)
Included in regulatory assets/liabilities	(44)	42	(39)
Settlements	(27)	6	38
Purchases			87
Transfers out of Level 3	1	3	(7)
Ending balance	64	150	139
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
Virginia Electric and Power Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	147	143	93
Total realized and unrealized gains (losses):
Included in regulatory assets/liabilities	(45)	40	(37)
Settlements	(25)	7	35
Purchases			(87)
Ending balance	60	147	143
Dominion Energy Gas Holdings, LLC
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	(2)	(2)	6
Total realized and unrealized gains (losses):
Included in other comprehensive income (loss)	1	(3)
Transfers out of Level 3	1	3	(8)
Ending balance		(2)	(2)
Operating Revenue
Total realized and unrealized gains (losses):
Included in earnings	(2)	3
Electric fuel and other energy-related purchases
Total realized and unrealized gains (losses):
Included in earnings	(15)	(42)	(35)
Electric fuel and other energy-related purchases | Virginia Electric and Power Company
Total realized and unrealized gains (losses):
Included in earnings	$ (17)	(43)	$ (35)
Purchased Gas
Total realized and unrealized gains (losses):
Included in earnings		$ 1

Fair Value Measurements (Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[1]	$ 29,952	$ 28,666
Credit facility borrowings		73
Junior subordinated notes	[2]	3,430	3,981
Remarketable subordinated notes	[2]	1,386	1,379
Carrying Amount | Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[2]	11,671	11,346
Carrying Amount | Dominion Energy Gas Holdings, LLC
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[3]	4,058	3,570
Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[1],[4]	31,045	31,233
Credit facility borrowings	[4]	73
Junior subordinated notes	[2],[4]	3,358	4,102
Remarketable subordinated notes	[2],[4]	1,340	1,446
Estimate of Fair Value | Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[2],[4]	12,400	12,842
Estimate of Fair Value | Dominion Energy Gas Holdings, LLC
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[3],[4]	$ 4,072	$ 3,719
[1]	Carrying amount includes amounts which represent, the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At December 31, 2018, and 2017, includes the valuation of certain fair value hedges associated with Dominion Energy's fixed rate debt of $(20) million and $(22) million, respectively.
[2]	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium.
[3]	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments.
[4]	Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

Fair Value Measurements (Fina_2

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Valuation of certain fair value hedges associated with fixed rate debt	$ (20)	$ (22)

Derivatives and Hedge Account_3

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	[1]	$ 287	$ 303
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		83	99
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		204	204
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		67	155
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		6	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		61	151
Dominion Energy Gas Holdings, LLC
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		29
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		2	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		27	30
Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	[1]	175	174
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		12	9
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		163	165
Commodity | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	[1]	68	80
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		68	80
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Commodity | Virginia Electric and Power Company | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		64	155
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		6	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		58	151
Commodity | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		3
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	[1]	18	17
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		1	8
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		17	9
Interest rate | Virginia Electric and Power Company | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		3
Foreign currency | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	[1]	26	32
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		2	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		24	30
Foreign currency | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets		26	32
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		2	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received		0	0
Net Amounts		$ 24	$ 30
[1]	Excludes $7 million and $4 million of derivative assets at December 31, 2018 and 2017, respectively, which are not subject to master netting or similar arrangements.

Derivatives and Hedge Account_4

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Offsetting Assets [Line Items]
Derivative assets, not subject to a master netting or similar arrangement	$ 7	$ 4
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Derivative assets, not subject to a master netting or similar arrangement	$ 26	$ 11

Derivatives and Hedge Account_5

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[1]	$ 278	$ 283
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		83	99
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		47	46
Net Amounts		148	138
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		94	61
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		6	4
Net Amounts		88	57
Dominion Energy Gas Holdings, LLC
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		19	8
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		2	2
Net Amounts		17	6
Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[1]	19	76
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		12	9
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral			6
Net Amounts		7	61
Commodity | Exchange
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[1]	115	120
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		68	80
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		47	40
Commodity | Virginia Electric and Power Company | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		6	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		6	4
Commodity | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet			6
Net Amounts			6
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[1]	142	85
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		1	8
Net Amounts		141	77
Interest rate | Virginia Electric and Power Company | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		88	57
Net Amounts		88	57
Interest rate | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		17
Net Amounts		17
Foreign currency | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[1]	2	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		2	2
Foreign currency | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		2	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		$ 2	$ 2
[1]	Excludes $1 million of derivative liabilities at December 31, 2018 and 2017, which are not subject to master netting or similar arrangements.

Derivatives and Hedge Account_6

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Offsetting Liabilities [Line Items]
Derivative liabilities, not subject to a master netting or similar arrangement	$ 1	$ 1
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Derivative liabilities, not subject to a master netting or similar arrangement	$ 9	$ 5

Derivatives and Hedge Account_7

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Detail)	12 Months Ended
	Dec. 31, 2018USD ($)MWhBcfgal
Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative [Line Items]
Volume of derivative activity | Bcf	27	[1]
Fixed Price - Natural Gas - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity | Bcf	8	[1]
Basis - Natural Gas - Non-current Derivative Contract [Member]
Derivative [Line Items]
Volume of derivative activity | Bcf	557
Basis - Natural Gas - Non-current Derivative Contract [Member] | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity | Bcf	488
Fixed Price - Electricity - Non-current Derivative Contract [Member]
Derivative [Line Items]
Volume of electricity | MWh	1,537,200	[1]
Financial Transmission Rights - Electricity- Non-current Derivative Contract [Member]
Derivative [Line Items]
Volume of electricity | MWh	0
Liquids - Non-current Derivative Contract [Member]
Derivative [Line Items]
Volume of derivative activity | gal	0	[2]
Interest Rate - Non-current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	$ 3,915,839,913	[3]
Interest Rate - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	1,200,000,000	[3]
Interest Rate - Non-current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	750,000,000
Foreign Exchange - Non- Current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	280,000,000	[3],[4]
Foreign Exchange - Non- Current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	$ 280,000,000
Fixed Price - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity | Bcf	56	[1]
Fixed Price - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity | Bcf	29	[1]
Basis - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity | Bcf	214
Basis - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity | Bcf	136
Fixed Price - Electricity - Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh	11,101,869	[1]
Fixed Price - Electricity - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh	367,019	[1]
Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh	45,351,415
Liquids - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity | gal	14,413,200	[2]
Liquids - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh	45,351,415
Interest Rate - Current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	$ 2,700,000,000	[3]
Interest Rate - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	700,000,000	[3]
Interest Rate - Current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	300,000,000
Foreign Exchange - Current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	$ 0	[3],[4]
NGLs | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Volume of derivative activity | gal	14,413,200
[1]	Includes options.
[2]	Includes NGLs and oil.
[3]	Maturity is determined based on final settlement period.
[4]	Euro equivalent volumes are € 250,000,000.

Derivatives and Hedge Account_8

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Parenthetical) (Detail) - Foreign currency	Dec. 31, 2018EUR (€)
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	€ 250,000,000
Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros)	€ 250,000,000

Derivatives and Hedge Account_9

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (235)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(2)
Commodity | Electricity
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	27
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 26
Maximum Term	24 months
Commodity | Other Energy Contract
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ 2
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 2
Maximum Term	3 months
Commodity | Natural Gas
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ 0
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 1
Maximum Term	36 months
Interest rate
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (276)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (29)
Maximum Term	396 months
Foreign currency
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ 12
Foreign currency, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (2)
Maximum Term	90 months
Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (25)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(4)
Dominion Energy Gas Holdings, LLC | Interest rate
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(39)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (4)
Maximum Term	312 months
Dominion Energy Gas Holdings, LLC | Foreign currency
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ 12
Foreign currency, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (2)
Maximum Term	90 months
Dominion Energy Gas Holdings, LLC | NGLs
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ 2
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 2
Maximum Term	3 months
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (13)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(1)
Virginia Electric and Power Company | Interest rate
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(13)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (1)
Maximum Term	384 months

Derivatives and Hedge Accoun_10

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Detail) - USD ($) $ in Millions		Dec. 31, 2018		Dec. 31, 2017
Derivatives Fair Value [Line Items]
Derivative Asset		$ 294		$ 307
Derivative Liabilities		279		284
Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		93		166
Derivative Liabilities		103		66
Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		29		32	[1]
Derivative Liabilities		19		8
Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[2]	223		169
Current Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		209		163
Current Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		14		6
Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		63		75
Current Assets | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		60		75
Current Assets | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		3
Current Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset	[3]	3
Current Assets | Dominion Energy Gas Holdings, LLC | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		3
Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	71		138
Noncurrent Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		41		95
Noncurrent Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		4		11
Noncurrent Assets | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		26		32
Noncurrent Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		30		91
Noncurrent Assets | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		30		91
Noncurrent Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		26	[1]	32
Noncurrent Assets | Dominion Energy Gas Holdings, LLC | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		26		32
Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities	[5]	157		250
Current Liabilities | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		129		195
Current Liabilities | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		26		53
Current Liabilities | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		2
Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		25		53
Current Liabilities | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		15		9
Current Liabilities | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		10		44
Current Liabilities | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[6]	11		8
Current Liabilities | Dominion Energy Gas Holdings, LLC | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities				6
Current Liabilities | Dominion Energy Gas Holdings, LLC | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		9
Current Liabilities | Dominion Energy Gas Holdings, LLC | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		2
Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	122		34
Noncurrent Liabilities [Member] | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		6		2
Noncurrent Liabilities [Member] | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		116		32
Noncurrent Liabilities [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		78		13
Noncurrent Liabilities [Member] | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		78		13
Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[8]	8
Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		8
Fair Value - Derivatives under Hedge Accounting [Member]
Derivatives Fair Value [Line Items]
Derivative Asset		105		54
Derivative Liabilities		166		191
Fair Value - Derivatives under Hedge Accounting [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		3
Derivative Liabilities		88		57
Fair Value - Derivatives under Hedge Accounting [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		29		32	[1]
Derivative Liabilities		19		8
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[2]	69		11
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		55		5
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		14		6
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		3
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		3
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset	[3]	3
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Dominion Energy Gas Holdings, LLC | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		3
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	36		43
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		6
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		4		11
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		26		32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		26	[1]	32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Dominion Energy Gas Holdings, LLC | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		26		32
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities	[5]	45		158
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		17		103
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		26		53
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		2
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		10		44
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		10		44
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[6]	11		8
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Dominion Energy Gas Holdings, LLC | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities				6
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Dominion Energy Gas Holdings, LLC | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		9
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Dominion Energy Gas Holdings, LLC | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		2
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	121		33
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		5		1
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		116		32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		78		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Virginia Electric and Power Company | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		78		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[8]	8
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		8
Derivatives Not Designated as Hedging Instruments
Derivatives Fair Value [Line Items]
Derivative Asset		189		253
Derivative Liabilities		113		93
Derivatives Not Designated as Hedging Instruments | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		90		166
Derivative Liabilities		15		9
Derivatives Not Designated as Hedging Instruments | Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[2]	154		158
Derivatives Not Designated as Hedging Instruments | Current Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		154		158
Derivatives Not Designated as Hedging Instruments | Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		60		75
Derivatives Not Designated as Hedging Instruments | Current Assets | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		60		75
Derivatives Not Designated as Hedging Instruments | Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	35		95
Derivatives Not Designated as Hedging Instruments | Noncurrent Assets | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		35		95
Derivatives Not Designated as Hedging Instruments | Noncurrent Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		30		91
Derivatives Not Designated as Hedging Instruments | Noncurrent Assets | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset		30		91
Derivatives Not Designated as Hedging Instruments | Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities	[5]	112		92
Derivatives Not Designated as Hedging Instruments | Current Liabilities | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		112		92
Derivatives Not Designated as Hedging Instruments | Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		15		9
Derivatives Not Designated as Hedging Instruments | Current Liabilities | Virginia Electric and Power Company | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		15		9
Derivatives Not Designated as Hedging Instruments | Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	1		1
Derivatives Not Designated as Hedging Instruments | Noncurrent Liabilities [Member] | Commodity
Derivatives Fair Value [Line Items]
Derivative Liabilities		$ 1		$ 1
[1]	Current derivative liabilities are presented in other current liabilities in Virginia Power's Consolidated Balance Sheets.
[2]	Current derivative assets are presented in other current assets in Dominion Energy'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 Dominion Energy's Consolidated Balance Sheets.
[5]	Current derivative liabilities are presented in other current liabilities in Dominion Energy's Consolidated Balance Sheets.
[6]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power's Consolidated Balance Sheets.
[7]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy's Consolidated Balance Sheets.
[8]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas' Consolidated Balance Sheets.

Derivatives and Hedge Accoun_11

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Detail) - Cash Flow Hedges - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	$ 40		$ 11	$ 92
Amount of Gain (Loss) Reclassified From AOCI to Income		(137)		47	259
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	39		(58)	(26)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[3]	2		(8)	(3)
Amount of Gain (Loss) Reclassified From AOCI to Income		(1)		(1)	(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4]	39		(58)	(26)
Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)		(23)		8	(26)
Amount of Gain (Loss) Reclassified From AOCI to Income		(27)		7	(15)
Commodity
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	64		1	164
Amount of Gain (Loss) Reclassified From AOCI to Income		(76)		79	307
Commodity | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)		1		(10)	(12)
Amount of Gain (Loss) Reclassified From AOCI to Income		(8)		(8)	4
Commodity | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(90)		81	330
Commodity | Operating Revenue | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(8)		(8)	4
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		14			(10)
Commodity | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				(2)	(13)
Interest rate
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1],[5]	(18)	[6]	(8)	(66)
Amount of Gain (Loss) Reclassified From AOCI to Income	[5]	(48)	[6]	(52)	(31)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2],[5]	39	[6]	(58)	(26)
Interest rate | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[3],[7]	2		(8)	(3)
Amount of Gain (Loss) Reclassified From AOCI to Income	[7]	(1)		(1)	(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4],[7]	39		(58)	(26)
Interest rate | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)		(18)			(8)
Amount of Gain (Loss) Reclassified From AOCI to Income		(6)		(5)	(2)
Foreign currency
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1],[8]	(6)		18	(6)
Amount of Gain (Loss) Reclassified From AOCI to Income	[8]	(13)		20	(17)
Foreign currency | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)		(6)		18	(6)
Amount of Gain (Loss) Reclassified From AOCI to Income		$ (13)		$ 20	$ (17)
[1]	Amounts deferred into AOCI have no associated effect in Dominion Energy'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 Energy's Consolidated Statements of Income.
[3]	Amounts deferred into AOCI have no associated effect in Virginia Power's Consolidated Statements of Income.
[4]	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.
[5]	Amounts recorded in Dominion Energy's Consolidated Statements of Income are classified in interest and related charges.
[6]	See Note 9 for amounts attributable to related parties.
[7]	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.
[8]	Amounts recorded in Dominion Energy's Consolidated Statements of Income are classified in other income.

Derivatives and Hedge Accoun_12

Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Detail) - Derivatives Not Designated as Hedging Instruments - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ (26)	$ (45)	$ (63)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2]	2	(57)	(70)
Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		(11)		1
Commodity | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(28)	18	2
Commodity | Operating Revenue | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2],[3]	2	(57)	(70)
Commodity | Operating Revenue | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		(11)		1
Commodity | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	11	(3)	4
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ (9)	(59)	(70)
Commodity | Other operations and maintenance
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]		$ (1)	$ 1
[1]	Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion Energy's Consolidated Statements of Income.
[2]	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.
[3]	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.

Earnings Per Share (Calculation

Earnings Per Share (Calculation of Basic and Diluted EPS) (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Earnings Per Share [Abstract]
Net Income Attributable to Dominion Energy		$ 641	$ 854	$ 449	$ 503	$ 1,312	$ 665	$ 390	$ 632	$ 2,447	$ 2,999	$ 2,123
Average shares of common stock outstanding - Basic										654.2	636	616.4
Net effect of dilutive securities	[1]									0.7		0.7
Average shares of common stock outstanding - Diluted										654.9	636	617.1
Earnings Per Common Share - Basic		$ 0.97	$ 1.31	$ 0.69	$ 0.77	$ 2.04	$ 1.03	$ 0.62	$ 1.01	$ 3.74	$ 4.72	$ 3.44
Earnings Per Common Share - Diluted		$ 0.97	$ 1.30	$ 0.69	$ 0.77	$ 2.04	$ 1.03	$ 0.62	$ 1.01	$ 3.74	$ 4.72	$ 3.44
[1]	Dilutive securities for 2018 consist primarily of forward sale agreements, effective April 2018 to December 2018. Dilutive securities for 2016 consist primarily of the 2013 Equity Units. See Notes 17 and 19 for more information.

Investments (Narrative) (Detail

Investments (Narrative) (Detail)		1 Months Ended					3 Months Ended		12 Months Ended
		Sep. 30, 2018USD ($)	Dec. 31, 2016USD ($)	Oct. 31, 2016USD ($)	May 31, 2016USD ($)	Sep. 30, 2014Membermi	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Mar. 31, 2019USD ($)
Schedule of Equity Method Investments [Line Items]
Equity in earnings on investments										$ 197,000,000	$ 14,000,000	$ 111,000,000
Distributions received from investment										209,000,000	419,000,000	104,000,000
Carrying amount of investment that exceeded share of underlying equity							$ 161,000,000	$ 249,000,000		161,000,000	249,000,000
Equity method investment goodwill							176,000,000	73,000,000		176,000,000	73,000,000
Equity in earnings on investments										197,000,000	(18,000,000)	111,000,000
Additional membership percentage interest purchased				3.00%
Payment for purchase of equity interest				$ 14,000,000
Other receivables	[1]						331,000,000	126,000,000		331,000,000	126,000,000
Contributions to equity method affiliates										428,000,000	370,000,000	198,000,000
Impairment charge										403,000,000	15,000,000	4,000,000
Liabilities, other deferred credits and other liabilities							17,075,000,000	16,631,000,000		17,075,000,000	16,631,000,000
Finite Lived Equity Method Investment Basis Difference [Member]
Schedule of Equity Method Investments [Line Items]
Carrying amount of investment that exceeded share of underlying equity							146,000,000	15,000,000		146,000,000	15,000,000
Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Equity in earnings on investments										24,000,000	21,000,000	21,000,000
Other receivables	[2]						17,000,000	15,000,000		17,000,000	15,000,000
Impairment charge							219,000,000			346,000,000	16,000,000
Liabilities, other deferred credits and other liabilities							2,944,000,000	2,866,000,000		2,944,000,000	2,866,000,000
Dominion Energy Gas Holdings, LLC | Partnership Interest
Schedule of Equity Method Investments [Line Items]
Distributions received from investment										28,000,000	24,000,000	22,000,000
Carrying amount of investment that exceeded share of underlying equity							8,000,000	8,000,000		8,000,000	8,000,000
Equity in earnings on investments										24,000,000	21,000,000	21,000,000
Trading Securities
Schedule of Equity Method Investments [Line Items]
Rabbi trust securities							111,000,000	112,000,000		111,000,000	112,000,000
Other Income [Member] | Dominion Energy Gas Holdings, LLC | Partnership Interest
Schedule of Equity Method Investments [Line Items]
Percentage of non-controlling partnership interest sold					0.65%
Sales price of non-controlling partnership interest					$ 7,000,000
Amount of gain from sale					5,000,000
Amount of after tax gain from sale					$ 3,000,000
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Distributions received from investment										36,000,000	270,000,000
Contributions to equity method affiliates										414,000,000	310,000,000	184,000,000
Atlantic Coast Pipeline | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Project cost estimates increase									$ 250,000,000
Atlantic Coast Pipeline | DETI
Schedule of Equity Method Investments [Line Items]
Revenue										203,000,000	129,000,000	$ 95,000,000
Other receivables							13,000,000	12,000,000		$ 13,000,000	12,000,000
Atlantic Coast Pipeline | Minimum | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Project cost estimates									7,250,000,000
Atlantic Coast Pipeline | Maximum | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Project cost estimates									$ 7,750,000,000
Atlantic Coast Pipeline | Previous Minimum
Schedule of Equity Method Investments [Line Items]
Project cost estimates							6,000,000,000
Atlantic Coast Pipeline | Current Minimum
Schedule of Equity Method Investments [Line Items]
Project cost estimates							7,000,000,000
Atlantic Coast Pipeline | Previous Maximum
Schedule of Equity Method Investments [Line Items]
Project cost estimates							6,500,000,000
Atlantic Coast Pipeline | Current Maximum
Schedule of Equity Method Investments [Line Items]
Project cost estimates							$ 7,500,000,000
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Distribution
Schedule of Equity Method Investments [Line Items]
Ownership interest (percentage)							48.00%			48.00%
Length of natural gas pipeline (in miles) | mi						600
Number of members | Member						3
Duration of contract						20 years
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Distribution | Duke Energy
Schedule of Equity Method Investments [Line Items]
Ownership interest (percentage)							47.00%			47.00%
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Distribution | Southern Company Gas [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (percentage)							5.00%			5.00%
Blue Racer
Schedule of Equity Method Investments [Line Items]
Amount of gain from sale							$ 546,000,000
Amount of after tax gain from sale							$ 390,000,000
Ownership interest percentage of limited partner interests							50.00%
Up-front cash consideration							$ 1,050,000,000
Additional deferred consideration, subject to increase for interest cost effective payable upon purchaser's availability of cash							150,000,000
Blue Racer | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Aggregate amount of contingent consideration, maximum													$ 300,000,000
Blue Racer | Oil and Gas Properties
Schedule of Equity Method Investments [Line Items]
Amount paid to repurchase portion of Western System from Blue Racer			$ 10,000,000
NedPower Mount Storm LLC
Schedule of Equity Method Investments [Line Items]
Liabilities, other deferred credits and other liabilities							1,000,000	17,000,000		$ 1,000,000	$ 17,000,000
NedPower Mount Storm LLC | Property, Plant and Equipment [Member]
Schedule of Equity Method Investments [Line Items]
Impairment charge								126,000,000
Impairment charge, after tax								$ 76,000,000
Fowler I Holdings LLC
Schedule of Equity Method Investments [Line Items]
Impairment charge							32,000,000
Impairment charge, after tax							20,000,000
Fair value of investment							$ 81,000,000			$ 81,000,000
Catalyst Old River Hydroelectric Limited Partnership
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of limited partner interests		25.00%
Limited partnership interest sale transaction, proceeds received		$ 91,000,000
Catalyst Old River Hydroelectric Limited Partnership | Other Income [Member]
Schedule of Equity Method Investments [Line Items]
Amount of gain from sale		87,000,000
Amount of after tax gain from sale		$ 63,000,000
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to related parties.

Investments (Equity and Debt Se

Investments (Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017
Investment Holdings [Line Items]
Amortized Cost, Total		$ 3,348		$ 3,200
Total Unrealized Gains		1,662		1,899
Total Unrealized Losses	[1]	(72)		(6)
Fair Value, Total		4,938		5,093
Fixed income securities Fair Value		1,604
Equity securities Total Unrealized Losses		(245)
Fixed Income
Investment Holdings [Line Items]
Cash equivalents and other Amortized Cost		4		34
Cash equivalents and other Fair Value		4		34
Common/collective trust funds | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	76		60
Fixed income securities Fair Value	[2]	76		60
Cost Method Investments [Member]
Investment Holdings [Line Items]
Amortized Cost, Total				68
Fair Value, Total				68
Equity securities: | U.S.
Investment Holdings [Line Items]
Equity securities Amortized Cost,	[3]	1,741		1,569
Equity securities Total Unrealized Gains	[3]	1,640		1,857
Equity securities Total Unrealized Losses	[3]	(51)
Equity securities Fair Value	[3]	3,330		3,426
Corporate debt instruments | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	435		430
Fixed income securities Total Unrealized Gains	[2]	5		15
Fixed income securities Total Unrealized Losses	[2]	(9)		(1)
Fixed income securities Fair Value	[2]	431		444
Government Securities | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	1,092		1,039
Fixed income securities Total Unrealized Gains	[2]	17		27
Fixed income securities Total Unrealized Losses	[2]	(12)		(5)
Fixed income securities Fair Value	[2]	1,097		1,061
Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total		1,643		1,549
Total Unrealized Gains		760		852
Total Unrealized Losses	[4]	(34)
Fair Value, Total		2,369		2,399
Fixed income securities Fair Value		778
Equity securities Total Unrealized Losses		(105)
Virginia Electric and Power Company | Common/collective trust funds | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	51		27
Fixed income securities Fair Value	[2]	51		27
Virginia Electric and Power Company | Cash Equivalents and Other [Member]
Investment Holdings [Line Items]
Cash equivalents and other Amortized Cost	[5]	6		22
Cash equivalents and other Fair Value		6		22
Virginia Electric and Power Company | Cost Method Investments [Member]
Investment Holdings [Line Items]
Amortized Cost, Total				68
Fair Value, Total				68
Virginia Electric and Power Company | Equity securities: | U.S.
Investment Holdings [Line Items]
Equity securities Amortized Cost,		858	[3]	734	[2]
Equity securities Total Unrealized Gains		751	[3]	831	[2]
Equity securities Total Unrealized Losses	[3]	(24)
Equity securities Fair Value		1,585	[3]	1,565	[2]
Virginia Electric and Power Company | Corporate debt instruments | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	224		216
Fixed income securities Total Unrealized Gains	[2]	2		8
Fixed income securities Fair Value	[2]	221		224
Virginia Electric and Power Company | Government Securities | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[2]	504		482
Fixed income securities Total Unrealized Gains	[2]	7		13
Fixed income securities Fair Value	[2]	$ 506		$ 493
[1]	The fair value of securities in an unrealized loss position was $833 million and $565 million at December 31, 2018 and 2017, respectively.
[2]	Unrealized gains and losses on equity securities (for 2017) and fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[3]	Effective January 2018, unrealized gains and losses on equity securities, including those previously classified as cost method investments, are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[4]	The fair value of securities in an unrealized loss position was $404 million and $234 million at December 31, 2018 and 2017, respectively.
[5]	Includes pending sales of securities of $6 million at both December 31, 2018 and 2017.

Investments (Equity and Debt _2

Investments (Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Investment Holdings [Line Items]
Net assets related to pending sales and purchases of securities		$ 5
Fair value of securities in an unrealized loss position	$ 833	565
Virginia Electric and Power Company
Investment Holdings [Line Items]
Net assets related to pending sales and purchases of securities	6	6
Fair value of securities in an unrealized loss position	$ 404	$ 234

Investments (Portion of Unreali

Investments (Portion of Unrealized Gains and Losses Relates to Equity Securities) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Investment Holdings [Line Items]
Net losses recognized during the period	$ (245)
Less: Net gains recognized during the period on securities sold during the period	(58)
Unrealized losses recognized during the period on securities still held at the end of the year	(303)	[1]
Virginia Electric and Power Company
Investment Holdings [Line Items]
Net losses recognized during the period	(105)
Less: Net gains recognized during the period on securities sold during the period	(32)
Unrealized losses recognized during the period on securities still held at the end of the year	$ (137)	[1]
[1]	Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Investments (Fair Value of our

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	$ 167
Due after one year through five years	389
Due after five years through ten years	376
Due after ten years	672
Total	1,604
Virginia Electric and Power Company
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	54
Due after one year through five years	156
Due after five years through ten years	210
Due after ten years	358
Total	$ 778

Investments (Selected Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales		$ 1,804	$ 1,831	$ 1,422
Realized gains	[1]	140	166	128
Realized losses	[1]	91	71	55
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales		887	849	733
Realized gains	[1]	60	75	63
Realized losses	[1]	$ 27	$ 30	$ 27
[1]	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) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	[1]	$ 30	$ 44	$ 51
Losses recorded to the nuclear decommissioning trust regulatory liability			(16)	(16)
Losses recognized in other comprehensive income (before taxes)		(30)	(5)	(12)
Net impairment losses recognized in earnings			23	23
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Total other-than-temporary impairment losses	[2]	15	20	26
Losses recorded to the nuclear decommissioning trust regulatory liability			(16)	(16)
Losses recognized in other comprehensive income (before taxes)		$ (15)	(2)	(7)
Net impairment losses recognized in earnings			$ 2	$ 3
[1]	Amounts include other-than-temporary impairment losses for debt securities of $5 million and $13 million at December 31, 2017 and 2016, respectively.
[2]	Amounts include other-than-temporary impairment losses for debt securities of $2 million and $8 million at December 31, 2017 and 2016 , respectively.

Investments (Recorded Other-T_2

Investments (Recorded Other-Than-Temporary Impairment Losses on Investments) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Other-than-temporary impairment losses for debt securities	$ 5	$ 13
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Other-than-temporary impairment losses for debt securities	$ 2	$ 8

Investments (Investments Under

Investments (Investments Under Equity Method of Accounting) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Investment Balance		$ 1,278	$ 1,544
Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%	[1]	50.00%
Investment Balance		$ 302	311
Description		Gas transmission system
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership%		48.00%
Investment Balance		$ 820	382
Description		Gas transmission system
Blue Racer
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment Balance			691
Description		Midstream gas and related services
Fowler I Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment Balance		$ 82	81
Description		Wind-powered merchant generation facility
Other Investment
Schedule of Equity Method Investments [Line Items]
Investment Balance	[2]	$ 74	79
Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Investment Balance		$ 91	95
Dominion Energy Gas Holdings, LLC | Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%		24.07%
Investment Balance		$ 91	$ 95
Description		Gas transmission system
[1]	Comprised of Dominion Energy Midstream's interest of 25.93% and Dominion Energy Gas' interest of 24.07%. See Note 15 for more information.
[2]	Liability of less than $1 million and $17 million associated with NedPower recorded to other deferred credits and other liabilities, on the Consolidated Balance Sheets as of December 31, 2018 and 2017, respectively. See additional discussion of NedPower below.

Investments (Investments Unde_2

Investments (Investments Under Equity Method of Accounting) (Parenthetical) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Liabilities, other deferred credits and other liabilities		$ 17,075	$ 16,631
Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%	[1]	50.00%
NedPower Mount Storm LLC
Schedule of Equity Method Investments [Line Items]
Liabilities, other deferred credits and other liabilities		$ 1	17
Dominion Energy Midstream Partners, LP | Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%		25.93%
Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Liabilities, other deferred credits and other liabilities		$ 2,944	$ 2,866
Dominion Energy Gas Holdings, LLC | Iroquois
Schedule of Equity Method Investments [Line Items]
Ownership%		24.07%
[1]	Comprised of Dominion Energy Midstream's interest of 25.93% and Dominion Energy Gas' interest of 24.07%. See Note 15 for more information.

Property, Plant and Equipment (

Property, Plant and Equipment (Property, Plant and Equipment) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Utility:
Generation	$ 19,250	$ 17,602
Transmission	16,669	15,335
Distribution	18,549	17,408
Storage	2,905	2,887
Nuclear fuel	1,626	1,599
Gas gathering and processing	307	219
Oil and gas	1,763	1,720
General and other	1,476	1,514
Plant under construction	2,385	7,765
Total utility	64,930	66,049
Nonutility:
Merchant generation-nuclear	1,550	1,452
Merchant generation-other	3,802	4,992
Nuclear fuel	1,025	968
Gas gathering and processing	185	630
LNG facility	3,977
Other-including plant under construction	1,109	732
Total nonutility	11,648	8,774
Total property, plant and equipment	76,578	74,823
Virginia Electric and Power Company
Utility:
Generation	19,250	17,602
Transmission	9,392	8,332
Distribution	11,785	11,151
Nuclear fuel	1,626	1,599
General and other	821	794
Plant under construction	1,639	2,840
Total utility	44,513	42,318
Nonutility:
Other-including plant under construction	11	11
Total property, plant and equipment	44,524	42,329
Dominion Energy Gas Holdings, LLC
Utility:
Transmission	4,758	4,732
Distribution	3,527	3,267
Storage	1,691	1,688
Gas gathering and processing	210	202
General and other	233	216
Plant under construction	494	293
Total utility	10,913	10,398
Nonutility:
Gas gathering and processing	185	630
Other-including plant under construction	140	145
Total nonutility	325	775
Total property, plant and equipment	$ 11,238	$ 11,173

Property, Plant and Equipment_2

Property, Plant and Equipment (Share of Jointly-Owned Power Stations) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Millstone Unit
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	93.50%	[1]
Plant in service	$ 1,231	[1]
Accumulated depreciation	(400)	[1]
Nuclear fuel	571	[1]
Accumulated amortization of nuclear fuel	(423)	[1]
Plant under construction	$ 66	[1]
Virginia Electric and Power Company | Bath Country Pumped Storage Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	60.00%	[2]
Plant in service	$ 1,058	[2]
Accumulated depreciation	(639)	[2]
Plant under construction	$ 6	[2]
Virginia Electric and Power Company | North Anna
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	88.40%	[2]
Plant in service	$ 2,560	[2]
Accumulated depreciation	(1,305)	[2]
Nuclear fuel	721	[2]
Accumulated amortization of nuclear fuel	(608)	[2]
Plant under construction	$ 103	[2]
Virginia Electric and Power Company | Clover Power Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	50.00%	[2]
Plant in service	$ 590	[2]
Accumulated depreciation	(240)	[2]
Plant under construction	$ 9	[2]
[1]	Unit jointly owned by Dominion Energy.
[2]	Units jointly owned by Virginia Power.

Property, Plant and Equipment_3

Property, Plant and Equipment (Narrative) (Detail) $ in Millions	1 Months Ended												3 Months Ended				12 Months Ended
	Sep. 30, 2018USD ($)	Aug. 31, 2018Project	Jun. 30, 2018USD ($)afield	Mar. 31, 2018USD ($)afield	Jan. 31, 2018USD ($)a	Dec. 31, 2017USD ($)	Sep. 30, 2017Project	Aug. 31, 2017USD ($)a	Jul. 31, 2017USD ($)a	Apr. 30, 2016a	Mar. 31, 2015USD ($)a	Nov. 30, 2014USD ($)afield	Mar. 31, 2019USD ($)MW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2020USD ($)MW	Dec. 31, 2019USD ($)MW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)a	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)a	Oct. 31, 2018USD ($)	Oct. 31, 2017USD ($)	Mar. 31, 2017USD ($)
Property, Plant and Equipment [Line Items]
Cost of project																			$ 151	$ 405	$ 40
Revenue recognized																			94
Virginia Electric and Power Company
Property, Plant and Equipment [Line Items]
Cost of project																			141	41	7
Revenue recognized																			25
Virginia Electric and Power Company | Two Solar Development Projects
Property, Plant and Equipment [Line Items]
Number of Projects | Project		2					2
Virginia Electric and Power Company | First Solar Development Project
Property, Plant and Equipment [Line Items]
Cost of project														$ 140
Dominion Energy Gas Holdings, LLC
Property, Plant and Equipment [Line Items]
Revenue recognized																			41
Dominion Energy Gas Holdings, LLC | Marcellus Shale | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Amount of consideration			$ 6		$ 28				$ 5			$ 120									$ 10		$ 200
Number of natural gas producers																							2
Development rights (number of acres) | a			9,000		18,000				2,000			24,000									4,000		100,000
Period for payments related to conveyance of natural gas storage fields												4 years											9 years
Proceeds from assignment of Shale Development Rights												$ 60										$ 16	$ 100
Gas and oil area developed net remaining interest conveyed percentage					50.00%				50.00%			50.00%									50.00%
Number of natural gas storage fields | field			1									1
Number of acres included in initial conveyance | a												12,000
Dominion Energy Gas Holdings, LLC | Marcellus Shale | Amended Agreement to Extend Conveyance of Development Rights | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Gain on sale															$ 9	$ 56
After tax gain on sale															5	$ 33
Development rights (number of acres) | a								70,000		70,000	9,000
Period for payments related to conveyance of natural gas storage fields											2 years
Gas and oil area developed net remaining interest conveyed percentage								68.00%		32.00%
Total consideration	$ 65							$ 130							65
Dominion Energy Gas Holdings, LLC | Marcellus Shale | Final Conveyance | Amended Agreement to Extend Conveyance of Development Rights | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Gain on sale	65
After tax gain on sale	47
Dominion Energy Gas Holdings, LLC | Utica and Point Pleasant Shale | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Amount of consideration				$ 16
Development rights (number of acres) | a				11,000
Proceeds from assignment of Shale Development Rights				$ 16
Number of natural gas storage fields | field				1
Dominion Energy Gas Holdings, LLC | Other operations and maintenance | Marcellus Shale | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Gain on sale			$ 6		$ 28				$ 5												$ 10
After tax gain on sale			$ 4		$ 20				$ 3												$ 6
Dominion Energy Gas Holdings, LLC | Other operations and maintenance | Marcellus Shale | Amended Agreement to Extend Conveyance of Development Rights | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Revenue recognized	35										$ 43
Revenue recognized net of tax	$ 21										$ 27
Dominion Energy Gas Holdings, LLC | Other operations and maintenance | Utica and Point Pleasant Shale | Oil and Gas Properties
Property, Plant and Equipment [Line Items]
Gain on sale				$ 16
After tax gain on sale				$ 12
Scenario, Forecast | Virginia Electric and Power Company
Property, Plant and Equipment [Line Items]
Cost of project													$ 37
MW capacity | MW													20
Scenario, Forecast | Virginia Electric and Power Company | Two Solar Development Projects
Property, Plant and Equipment [Line Items]
MW capacity | MW																	155	155
Scenario, Forecast | Virginia Electric and Power Company | First Solar Development Project
Property, Plant and Equipment [Line Items]
Cost of project																		$ 120
Scenario, Forecast | Virginia Electric and Power Company | Second Solar Development Project
Property, Plant and Equipment [Line Items]
Cost of project																	$ 130	$ 140
Retail Energy Marketing Assets | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Property, Plant and Equipment [Line Items]
Amount of consideration																									$ 143
Contractual term of agreement to use brand						10 years
Gain on sale						$ 78								65
After tax gain on sale						48								49
Retail Energy Marketing Assets | Disposal Group, Disposed of by Sale, Not Discontinued Operations | First Phase of Agreements to Sell Certain Assets
Property, Plant and Equipment [Line Items]
Amount of consideration						$ 79									$ 79					79
Retail Energy Marketing Assets | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Second Phase of Agreements to Sell Certain Assets
Property, Plant and Equipment [Line Items]
Amount of consideration																								$ 63
Fairless and Manchester
Property, Plant and Equipment [Line Items]
Amount of consideration														1,200					1,200
Gain on sale of equity method investment																			210
Gain on sale of equity method investments, net of tax																			198
Assignment of Tower Rental Portfolio | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Virginia Electric and Power Company
Property, Plant and Equipment [Line Items]
Amount of consideration																										$ 91
Amount recognized in operating revenue and other income from sale																			6	$ 11
Amount to be recognized in other income ratably through 2023														$ 29					$ 29

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets (Goodwill) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	$ 6,405	$ 6,399
Purchase Accounting Adjustment		5
Dominion Questar Combination			6
Goodwill, Ending Balance	[1]	6,410	6,405
Dominion Energy Gas Holdings, LLC
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	542	542
Purchase Accounting Adjustment		5
No events affecting goodwill			0
Goodwill, Ending Balance	[1]	547	542
Operating Segments | Power Generation
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	1,422	1,422
Goodwill, Ending Balance	[1]	1,422	1,422
Operating Segments | Gas Infrastructure
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	4,057	4,051
Purchase Accounting Adjustment		5
Dominion Questar Combination	[2]		6
Goodwill, Ending Balance	[1]	4,062	4,057
Operating Segments | Power Delivery
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	926	926
Goodwill, Ending Balance	[1]	926	926
Operating Segments | Dominion Energy Gas Holdings, LLC | Power Generation
Goodwill [Roll Forward]
No events affecting goodwill			0
Operating Segments | Dominion Energy Gas Holdings, LLC | Gas Infrastructure
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	542	542
Purchase Accounting Adjustment		5
No events affecting goodwill			0
Goodwill, Ending Balance	[1]	$ 547	542
Operating Segments | Dominion Energy Gas Holdings, LLC | Power Delivery
Goodwill [Roll Forward]
No events affecting goodwill			0
Operating Segments | Dominion Energy Gas Holdings, LLC | Corporate and Other
Goodwill [Roll Forward]
No events affecting goodwill	[3]		$ 0
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	See Note 3.
[3]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets (Narrative) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Goodwill [Line Items]
Amortization expense for intangible assets	$ 82	$ 80	$ 73
Acquisition of intangible assets	$ 127
Weighted-average amortization period (years)	15 years
Virginia Electric and Power Company
Goodwill [Line Items]
Amortization expense for intangible assets	$ 31	31	29
Acquisition of intangible assets	$ 49
Weighted-average amortization period (years)	11 years
Dominion Energy Gas Holdings, LLC
Goodwill [Line Items]
Amortization expense for intangible assets	$ 14	$ 14	$ 6
Acquisition of intangible assets	$ 14
Weighted-average amortization period (years)	10 years

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets (Components of Intangible Assets) (Detail) - Computer Software, Intangible Asset [Member] - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 1,033	$ 1,043
Accumulated Amortization	363	358
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	384	347
Accumulated Amortization	134	114
Dominion Energy Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	174	165
Accumulated Amortization	$ 65	$ 56

Goodwill and Intangible Asset_5

Goodwill and Intangible Assets (Annual Amortization Expense of Intangible Assets) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Finite-Lived Intangible Assets [Line Items]
2,019	$ 67
2,020	56
2,021	44
2,022	34
2,023	23
Virginia Electric and Power Company
Finite-Lived Intangible Assets [Line Items]
2,019	29
2,020	23
2,021	16
2,022	12
2,023	6
Dominion Energy Gas Holdings, LLC
Finite-Lived Intangible Assets [Line Items]
2,019	14
2,020	13
2,021	12
2,022	8
2,023	$ 7

Regulatory Assets and Liabili_3

Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Regulatory Assets [Line Items]
Regulatory assets-current		$ 496	$ 294
Regulatory assets-noncurrent		2,676	2,480
Total regulatory assets		3,172	2,774
Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current		424	205
Regulatory assets-noncurrent		737	810
Total regulatory assets		1,161	1,015
Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	29	26
Regulatory assets-noncurrent		727	511
Total regulatory assets		756	537
Deferred nuclear refueling outage costs
Regulatory Assets [Line Items]
Regulatory assets-current	[2]	$ 69	54
Deferred nuclear refueling outage costs | Maximum
Regulatory Assets [Line Items]
Amortization period for deferred costs		18 months
Deferred nuclear refueling outage costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[2]	$ 69	54
Deferred cost of fuel used in electric generation
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	174	23
Regulatory assets-noncurrent	[3]	83
Deferred cost of fuel used in electric generation | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	174	23
Regulatory assets-noncurrent	[3]	83
Deferred rate adjustment clause costs
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	96	70
Regulatory assets-noncurrent	[4]	329	401
Deferred rate adjustment clause costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	78	56
Regulatory assets-noncurrent	[4]	230	312
Deferred rate adjustment clause costs | Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	18	14
Regulatory assets-noncurrent	[4]	99	89
Unrecovered gas costs
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	14	38
Unrecovered gas costs | Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	9	8
Other
Regulatory Assets [Line Items]
Regulatory assets-current		143	109
Regulatory assets-noncurrent		187	151
Other | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current		103	72
Regulatory assets-noncurrent		81	86
Other | Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-current		2	4
Regulatory assets-noncurrent		32	17
Unrecognized pension and other postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[6]	1,497	1,336
Unrecognized pension and other postretirement benefit costs | Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[6]	392	258
Utility reform legislation
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[7]	204	147
Utility reform legislation | Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[7]	204	147
PJM transmission rates
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[8]	192	222
PJM transmission rates | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[8]	192	222
Derivatives
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[9]	184	223
Derivatives | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[9]	$ 151	$ 190
[1]	Current regulatory assets are presented in other current assets in Dominion Energy Gas' Consolidated Balance Sheets.
[2]	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.
[3]	Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power's generation operations. See Note 13 for more information.
[4]	Primarily reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power and deferrals of costs associated with certain current and prospective rider projects for Dominion Energy Gas. See Note 13 for more information.
[5]	Reflects unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings with the applicable regulatory authority.
[6]	Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy and Dominion Energy Gas' rate-regulated subsidiaries.
[7]	Ohio legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date cost levels when filing rate cases. It also allows gas companies to seek approval of capital expenditure plans under which gas companies can recognize carrying costs on associated capital investments placed in service and can defer the carrying costs plus depreciation and property tax expenses for recovery from ratepayers in the future.
[8]	Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information.
[9]	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.

Regulatory Assets and Liabili_4

Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]	$ 356	$ 193
Regulatory liabilities-noncurrent		6,840	6,916
Total regulatory liabilities		7,196	7,109
Provision for future cost of removal and AROs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[2]	117	101
Regulatory liabilities-noncurrent	[2]	1,409	1,384
Reserve for rate credits to customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	71
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		64	92
Regulatory liabilities-noncurrent		265	284
Nuclear decommissioning trust
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[4]	1,070	1,121
Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[5]	4,071	4,058
Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[6]	104
Derivatives
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[7]	25	69
Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		299	127
Regulatory liabilities-noncurrent		4,647	4,760
Total regulatory liabilities		4,946	4,887
Virginia Electric and Power Company | Reserve for rate credits to customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	71
Virginia Electric and Power Company | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		41	47
Regulatory liabilities-noncurrent		33	74
Virginia Electric and Power Company | Nuclear decommissioning trust
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[4]	1,070	1,121
Virginia Electric and Power Company | Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[5]	2,579	2,581
Virginia Electric and Power Company | Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[6]	95
Virginia Electric and Power Company | Provision for future cost of removal
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[2]	92	80
Regulatory liabilities-noncurrent	[2]	940	915
Virginia Electric and Power Company | Derivatives
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[7]	25	69
Dominion Energy Gas Holdings, LLC
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]	21	38
Regulatory liabilities-noncurrent		1,285	1,227
Total regulatory liabilities		1,306	1,265
Dominion Energy Gas Holdings, LLC | Provision for future cost of removal and AROs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[2]	14	13
Regulatory liabilities-noncurrent	[2]	158	160
Dominion Energy Gas Holdings, LLC | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		4	5
Regulatory liabilities-noncurrent		97	69
Dominion Energy Gas Holdings, LLC | Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[5]	1,011	998
Dominion Energy Gas Holdings, LLC | Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[6]	19
Dominion Energy Gas Holdings, LLC | PIPP
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[8]	$ 3	$ 20
[1]	Current regulatory liabilities are presented in other current liabilities in Dominion Energy and Dominion Energy Gas' Consolidated Balance Sheets.
[2]	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.
[3]	Charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers. See Note 13 for more information.
[4]	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.
[5]	Amounts recorded to pass the effect of reduced income tax rates from the 2017 Tax Reform Act to customers in future periods, which will reverse at the weighted average tax rate that was used to build the reserves over the remaining book life of the property, net of amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity.
[6]	Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at the Companies' regulated electric generation and electric and natural gas distribution operations. See Note 13 for more information.
[7]	As discussed under Derivative Instruments in Note 2, for jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers.
[8]	Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information.

Regulatory Assets and Liabili_5

Regulatory Assets and Liabilities (Narrative) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Public Utilities General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 396
Period for which expenditures are expected to be recovered	2 years
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 300
Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 12

Regulatory Matters (Narrative)

Regulatory Matters (Narrative) (Detail) MMcf in Millions, Customer in Millions, $ in Millions

Feb. 01, 2020

Jan. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Nov. 30, 2018USD ($)ProjectMWmi

Oct. 31, 2018USD ($)Program

Oct. 30, 2018MMcf

Sep. 30, 2018USD ($)

Aug. 31, 2018USD ($)MMBTU

Jul. 31, 2018USD ($)Facility

Jun. 30, 2018USD ($)kVSegment

May 31, 2018USD ($)

Apr. 30, 2018USD ($)

Mar. 31, 2018USD ($)

May 31, 2017USD ($)

Nov. 30, 2015USD ($)kVmi

Jun. 30, 2015USD ($)Buildings

Mar. 31, 2015USD ($)

Nov. 30, 2013kVmi

Aug. 31, 2009kV

Dec. 31, 2007Customer

Apr. 30, 2007kV

Jan. 31, 2020

Dec. 31, 2019USD ($)

Mar. 31, 2019USD ($)

Dec. 31, 2018USD ($)kVSegmentsmi

Aug. 31, 2018USD ($)MMBTU

Mar. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Jul. 31, 2017USD ($)

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

$ 2,676

$ 2,676

$ 2,480

Reduction in regulatory liabilities

35

4,200

Annual regulatory liability deferral amount

0.4

$ 0.4

Separate segments | Segments

3

Asset impairment pre tax charge

$ 403

15

$ 4

Virginia Electric and Power Company

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

737

737

810

Tax reform benefit

$ 100

Reduction in regulatory liabilities

$ 14

$ 31

2,600

Regulatory liabilities one time bill credit amount

13

Separate segments | Segments

2

Virginia Electric and Power Company | Minimum

Public Utilities General Disclosures [Line Items]

Facility operating capacity (kV) | kV

500

Virginia Electric and Power Company | Minimum | Judicial Ruling

Public Utilities General Disclosures [Line Items]

Facility operating capacity (kV) | kV

500

Virginia Electric and Power Company | Scenario, Forecast

Public Utilities General Disclosures [Line Items]

Asset impairment pre tax charge

$ 190

Virginia Electric and Power Company | FERC-regulated | Settled Litigation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Other Deferred Credits And Other Liabilities

Public Utilities General Disclosures [Line Items]

Amount of contingent liability

50

$ 50

Virginia Electric and Power Company | FERC-regulated | Settled Litigation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Current Liabilities

Public Utilities General Disclosures [Line Items]

Amount of contingent liability

126

126

Virginia Electric and Power Company | FERC-regulated | Settled Litigation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | PJM transmission rates

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

$ 265

$ 265

Duration of payment under settlement agreement

10 years

Amount required to pay under settlement agreement

$ 276

Virginia Electric and Power Company | Virginia Regulation

Public Utilities General Disclosures [Line Items]

Proposed annual revenue reduction amount

151

190

Interim rate reduction amount

$ 125

Rate reduction

50

One-time bill credit, provisions for current customers

200

Charge associated with legislation

215

Charge associated with legislation, after tax

$ 160

Legislation amount credited in customer bill

138

Proposed revenue requirement

$ 1,500

Increase in fuel revenue

209

222

Capacity of transmission line (kV) | kV

115

Obligated to make payments to fund improvement for historical and cultural resources

$ 90

Payments made to fund improvement for historical and cultural resources

90

Virginia Electric and Power Company | Virginia Regulation | Operating Segments

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 628

636

$ 755

Virginia Electric and Power Company | Virginia Regulation | Transmission Component of Virginia Power's | Operating Segments

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

468

Virginia Electric and Power Company | Virginia Regulation | Coastal Virginia Offshore Wind Project

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

$ 300

Capacity of wind turbine generators | MW

6

Public utilities length of wind project | mi

27

Number of wind projects | Project

2

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

Public Utilities General Disclosures [Line Items]

Length of kV line (miles) | mi

7

Capacity of transmission line (kV) | kV

500

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

Public Utilities General Disclosures [Line Items]

Length of kV line (miles) | mi

20

Capacity of transmission line (kV) | kV

230

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

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

$ 180

Length of kV line (miles) | mi

5

Capacity of transmission line (kV) | kV

230

Virginia Electric and Power Company | Virginia Regulation | Double Circuit Transmission Line Between Near Gainesville Substation And Haymarket Substation

Public Utilities General Disclosures [Line Items]

Capacity of transmission line (kV) | kV

230

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Between Idylwood and Tysons Substations

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

125

$ 30

$ 125

Length of kV line (miles) | mi

4

Capacity of transmission line (kV) | kV

230

230

Separate segments | Segment

4

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Between The Idylwood And Tysons Substations

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

816

$ 816

Operations and maintenance expenses

102

Virginia Electric and Power Company | Virginia Regulation | Rider T1 | Operating Segments

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

630

287

Increase (decrease) in revenue requirement

$ (146)

Virginia Electric and Power Company | Virginia Regulation | Rider U

Public Utilities General Disclosures [Line Items]

Approved revenue required

70

$ 73

Virginia Electric and Power Company | Virginia Regulation | Riders C1A and C2A | Energy Efficiency Program | Operating Segments

Public Utilities General Disclosures [Line Items]

Increase (decrease) in revenue requirement

18

Approved revenue required

$ 49

Number of new energy efficiency programs | Program

10

Period for cost cap

5 years

Number of new demand response programs | Program

1

Amount of cost recovery

$ 262

Virginia Electric and Power Company | Virginia Regulation | Solar Development Project

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

$ 410

Number of solar facility | Facility

2

Virginia Electric and Power Company | Virginia Regulation | Solar Development Project | Rider US-3 | Operating Segments

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 10

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event

Public Utilities General Disclosures [Line Items]

Proposed annual revenue reduction amount

$ 171

Expected annual revenue reduction on one-time bill credit

120

Interim rate reduction amount

120

Legislation amount credited in customer bill

77

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event | Transmission Line Between The Idylwood And Tysons Substations

Public Utilities General Disclosures [Line Items]

The total estimated capital investment

$ 68

Virginia Electric and Power Company | Virginia Regulation | Subsequent Event | Solar Development Project | Rider US-3 | Operating Segments

Public Utilities General Disclosures [Line Items]

Performance guarantee of the facilities

20 years

Solar capacity factor when normalized for force majeure events

25.00%

Virginia Electric and Power Company | Virginia Regulation | Third Phase | Rider U

Public Utilities General Disclosures [Line Items]

Projected capital investment

179

179

Virginia Electric and Power Company | Virginia Regulation | Second Phase | Rider U

Public Utilities General Disclosures [Line Items]

Projected capital investment

64

65

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

Public Utilities General Disclosures [Line Items]

Increase (decrease) in revenue requirement

$ 24

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

Public Utilities General Disclosures [Line Items]

Increase (decrease) in revenue requirement

$ 24

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

Public Utilities General Disclosures [Line Items]

Mitigation recoverable percentage

50.00%

Mitigation recoverable remaining percentage

50.00%

DETI

Public Utilities General Disclosures [Line Items]

Expected cost of project

$ 95

Agreement to provide Dths per day of transportation service | MMBTU

150,000

150,000

DETI | FERC-regulated | Supply Header Project | Atlantic Coast Pipeline

Public Utilities General Disclosures [Line Items]

Annual electric power cost rate adjustment, approval amount requested to recover amount

$ 7

Annual transportation cost rate adjustment, approval amount requested to recover amount

$ 37

DETI | FERC-regulated | Preliminary recommendation one | Other operations and maintenance

Public Utilities General Disclosures [Line Items]

Audit compliance charge recognized in connection with preliminary recommendation

129

15

Audit compliance after-tax charge recognized in connection with preliminary recommendation

94

9

Questar Gas | Cost-of-service impact of 2017 Tax Reform Act

Public Utilities General Disclosures [Line Items]

Reduction in regulatory liabilities

$ 15

Refund to customers related to deferred corporate income tax reduction

$ 9

Regulatory liability, amortization period

1 year

Questar Gas | Utah and Wyoming Regulation | Pipeline Infrastructure Replacement Program

Public Utilities General Disclosures [Line Items]

Projected capital investment

85

Questar Gas | Utah and Wyoming Regulation | Fuel Deferral [Member]

Public Utilities General Disclosures [Line Items]

Proposed cost increase (decrease) amount

$ 48

$ 86

LNG peaking storage facility, liquefaction rate per day | MMcf

8.2

Questar Gas | Utah and Wyoming Regulation | Scenario, Forecast | Pipeline Infrastructure Replacement Program

Public Utilities General Disclosures [Line Items]

Public utilities additional revenue to be collected

11

East Ohio | Ohio Regulation | Pipeline Infrastructure Replacement Program

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

165

Percentage replacement of pipeline system

25.00%

Period for capital investment

5 years

Actual cumulative PREP Investment

$ 200

Annual percentage increase in capital investment

3.00%

Total estimated cost

1,400

1,400

204

East Ohio | Ohio Regulation | Automated Meter Reading Program

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 5

Number of customers with automated meter reading technology | Customer

1.2

East Ohio | Ohio Regulation | Percentage Of Income Payment Plan Rider

Public Utilities General Disclosures [Line Items]

Refund of over-recovery of accumulated arrearages

10

Recovery of projected deferred program costs

$ 4

East Ohio | Ohio Regulation | UEX Rider

Public Utilities General Disclosures [Line Items]

Elimination of over-recovered balance of accumulated bad debt expense

$ 11

East Ohio | Ohio Regulation | Demand Side Management Costs

Public Utilities General Disclosures [Line Items]

Annual electric power cost rate adjustment, approval amount requested to recover amount

$ 4

East Ohio | Ohio Regulation | Scenario, Forecast | UEX Rider

Public Utilities General Disclosures [Line Items]

Recovery of prospective net bad debt expense

$ 16

Hope Gas, Inc. | West Virginia Regulation | PREP

Public Utilities General Disclosures [Line Items]

Projected capital investment

31

Amount of cost recovery

$ 8

28

Actual cumulative PREP Investment

48

Annual PREP costs recovered

$ 7

Projected PREP investment

31

31

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

Public Utilities General Disclosures [Line Items]

Projected capital investment

36

Projected PREP investment

$ 29

Cove Point | FERC-regulated | Supply Header Project | Atlantic Coast Pipeline

Public Utilities General Disclosures [Line Items]

Annual transportation cost rate adjustment, approval amount requested to recover amount

$ 30

Public utilities expected cost to acquire productive assets

$ 150

Public utilities number of binding precedent agreements for project facilities | Buildings

2

Estimated Cost of project

45

Asset impairment pre tax charge

37

Asset impairment after tax charge

$ 28

$ 28

Regulatory Matters - Additional

Regulatory Matters - Additional Significant Riders (Detail) - Virginia Electric and Power Company $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Rider S
Public Utilities General Disclosures [Line Items]
Application Date	2018-06
Approval Date	February 2,019
Rate Year Beginning	2019-04
Total Revenue Requirement (millions)	$ 215
Increase (Decrease) Over Previous Year (millions)	$ (3)
Rider GV
Public Utilities General Disclosures [Line Items]
Application Date	2018-06
Approval Date	February 2,019
Rate Year Beginning	2019-04
Total Revenue Requirement (millions)	$ 120
Increase (Decrease) Over Previous Year (millions)	$ 38
Rider W
Public Utilities General Disclosures [Line Items]
Application Date	2018-06
Approval Date	February 2,019
Rate Year Beginning	2019-04
Total Revenue Requirement (millions)	$ 105
Increase (Decrease) Over Previous Year (millions)	$ (4)
Rider R
Public Utilities General Disclosures [Line Items]
Application Date	2018-06
Approval Date	February 2,019
Rate Year Beginning	2019-04
Total Revenue Requirement (millions)	$ 57
Increase (Decrease) Over Previous Year (millions)	$ (9)
Rider B
Public Utilities General Disclosures [Line Items]
Application Date	2018-06
Approval Date	February 2,019
Rate Year Beginning	2019-04
Total Revenue Requirement (millions)	$ 38
Increase (Decrease) Over Previous Year (millions)	$ (9)
Rider BW
Public Utilities General Disclosures [Line Items]
Application Date	2018-10
Approval Date	Pending
Rate Year Beginning	2019-09
Total Revenue Requirement (millions)	$ 123
Increase (Decrease) Over Previous Year (millions)	$ 7
Rider US-2
Public Utilities General Disclosures [Line Items]
Application Date	2018-10
Approval Date	Pending
Rate Year Beginning	2019-09
Total Revenue Requirement (millions)	$ 16
Increase (Decrease) Over Previous Year (millions)	$ 3
Rider E
Public Utilities General Disclosures [Line Items]
Application Date	2018-12
Approval Date	Pending
Rate Year Beginning	2019-11
Total Revenue Requirement (millions)	$ 114

Regulatory Matters - Summary of

Regulatory Matters - Summary of Additional Significant Virginia Power Electric Transmission Projects Approved and Applied (Detail) - Virginia Electric and Power Company - Virginia Regulation $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2018USD ($)kV	Dec. 31, 2018USD ($)kVmi
Public Utilities General Disclosures [Line Items]
Capacity of transmission line (kV)		115
Transmission Lines Between Possum Point Switching Station And Novec's Smoketown Delivery Point [Member]
Public Utilities General Disclosures [Line Items]
Application Date		2017-06
Approval Date		2018-02
Capacity of transmission line (kV)		230
Length of kV line (miles) | mi		9
Total estimated cost of project | $		$ 20
Transmission Line Between Dooms Substation And Valley Substation [Member]
Public Utilities General Disclosures [Line Items]
Application Date		2017-09
Approval Date		2018-09
Capacity of transmission line (kV)		500
Length of kV line (miles) | mi		18
Total estimated cost of project | $		$ 65
Transmission Line Between Idylwood and Tysons Substations
Public Utilities General Disclosures [Line Items]
Application Date		2017-11
Approval Date		2018-09
Capacity of transmission line (kV)	230	230
Length of kV line (miles) | mi		4
Total estimated cost of project | $	$ 30	$ 125
Transmission Lines Between Chesterfield and Hopewell Substations
Public Utilities General Disclosures [Line Items]
Application Date		2018-05
Approval Date		2018-11
Capacity of transmission line (kV)		230
Length of kV line (miles) | mi		8
Total estimated cost of project | $		$ 30
Transmission Lines Between Chesterfield and Lakeside Substations
Public Utilities General Disclosures [Line Items]
Application Date		2018-05
Approval Date		2018-12
Capacity of transmission line (kV)		230
Length of kV line (miles) | mi		21
Total estimated cost of project | $		$ 35
Transmission Lines Between Landstown and Thrasher Substations
Public Utilities General Disclosures [Line Items]
Application Date		2018-06
Approval Date		2018-12
Capacity of transmission line (kV)		230
Length of kV line (miles) | mi		8.5
Total estimated cost of project | $		$ 20
Transmission Line In Alleghany Country Virginia And Covington Virginia
Public Utilities General Disclosures [Line Items]
Application Date		2018-08
Capacity of transmission line (kV)		138
Length of kV line (miles) | mi		5
Total estimated cost of project | $		$ 15
Build a new substation and connect three existing transmission lines thereto in Fluvanna County, Virginia
Public Utilities General Disclosures [Line Items]
Application Date		2018-10
Capacity of transmission line (kV)		230
Total estimated cost of project | $		$ 30
Maximum | Build a new substation and connect three existing transmission lines thereto in Fluvanna County, Virginia
Public Utilities General Disclosures [Line Items]
Length of kV line (miles) | mi		1

Asset Retirement Obligations (C

Asset Retirement Obligations (Changes to AROs) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018		Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		$ 2,432	[1]	$ 2,485
Obligations incurred during the period		20		37
Obligations settled during the period		(159)		(214)
Revisions in estimated cash flows		120	[2]	7
Accretion		119		117
AROs, Ending balance	[1]	2,532		2,432
Virginia Electric and Power Company
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		1,365		1,443
Obligations incurred during the period		14		11
Obligations settled during the period		(119)		(152)
Revisions in estimated cash flows		120	[2]	(1)
Accretion		65		64
AROs, Ending balance		1,445		1,365
Dominion Energy Gas Holdings, LLC
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs, Beginning balance		160	[3]	156
Obligations incurred during the period		4		2
Obligations settled during the period		(6)		(7)
Accretion		9		9
AROs, Ending balance	[3]	$ 167		$ 160
[1]	Includes $263 million and $282 million reported in other current liabilities at December 31, 2017, and 2018, respectively.
[2]	Reflects future ash pond and landfill closure costs at certain utility generation facilities. See Note 22 for further information.
[3]	Includes $146 million and $153 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2017 and 2018, respectively.

Asset Retirement Obligations _2

Asset Retirement Obligations (Changes to AROs) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligations [Line Items]
Asset retirement obligations, non current	$ 2,250	$ 2,169
Current Liabilities
Asset Retirement Obligations [Line Items]
Asset retirement obligation, current	282	263
Other Deferred Credits And Other Liabilities | Dominion Energy Gas Holdings, LLC
Asset Retirement Obligations [Line Items]
Asset retirement obligations, non current	$ 153	$ 146

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligations [Line Items]
Nuclear decommissioning trust funds	$ 4,938	$ 5,093
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
Nuclear decommissioning trust funds	$ 2,369	$ 2,399

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)MWGenerators	Dec. 31, 2016USD ($)
Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Securities due within one year	$ 350	$ 850
Long term debt	11,321	10,496
Payables to affiliates	209	125
Dominion Energy Gas Holdings, LLC
Variable Interest Entity [Line Items]
Securities due within one year	449
Long term debt	3,609	3,570
Payables to affiliates	$ 65	62
Variable Interest Entity, Primary Beneficiary | Partnership Interest | Merchant Solar Projects
Variable Interest Entity [Line Items]
Initial membership interest percentage	67.00%
Variable Interest Entity, Primary Beneficiary | Dominion Energy Midstream Partners, LP | Partnership Interest | Limited Partner
Variable Interest Entity [Line Items]
Percentage of limited partner interests in Dominion Midstream Partners, LP	60.90%
Variable Interest Entity, Primary Beneficiary | Dominion Energy Midstream Partners, LP | Partnership Interest | Preferred Partner
Variable Interest Entity [Line Items]
Percentage of limited partner interests in Dominion Midstream Partners, LP	37.50%
Variable Interest Entity, Primary Beneficiary | SBL Holdco
Variable Interest Entity [Line Items]
Securities due within one year	$ 31
Long term debt	$ 299
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	48.00%
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company | DES
Variable Interest Entity [Line Items]
Shared services purchased	$ 335	340	$ 346
Payables to affiliates	107	36
Variable Interest Entity, Not Primary Beneficiary | Dominion Energy Gas Holdings, LLC | DES
Variable Interest Entity [Line Items]
Shared services purchased	126	126	123
Payables to affiliates	46	$ 14
Variable Interest Entity (VIE) or Potential VIE, Information Unavailability | Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Long term capacity contract non utility generators (generators) | Generators		3
Number of expired non-utility generators | Generators		2
Aggregate generation capacity from long-term power and capacity contracts (MW) | MW		218
Remaining purchase commitments	150
Payment for electric capacity	50	$ 86	144
Payment for electric energy	$ 18	$ 24	$ 31

Short-Term Debt and Credit Ag_3

Short-Term Debt and Credit Agreements (Narrative) (Detail) - USD ($)	1 Months Ended		12 Months Ended
	Jun. 30, 2018	Feb. 28, 2018	Dec. 31, 2018		Oct. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Facility Limit			$ 6,000,000,000	[1]			$ 5,500,000,000
Short-term debt			334,000,000				3,298,000,000
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Facility Limit			1,500,000,000	[2]			1,500,000,000
Short-term debt			10,000,000				629,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
Facility Limit			6,000,000,000	[3]			5,500,000,000
Short-term debt			314,000,000				$ 542,000,000
Credit facility			100,000,000
Dominion Energy Midstream Partners, LP
Debt Instrument [Line Items]
Facility Limit						$ 500,000,000
Credit facility, outstanding amount			73,000,000
Six Billion Joint Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit			6,000,000,000			6,000,000,000
Six Billion Joint Revolving Credit Facility | Questar Gas
Debt Instrument [Line Items]
Facility Limit			250,000,000
Six Billion Joint Revolving Credit Facility | Virginia Electric and Power Company
Debt Instrument [Line Items]
Facility Limit			1,500,000,000
Credit Facilities, Maturing in December 2018 with 1 year Automatic Renewals through 2023 | SBL Holdco
Debt Instrument [Line Items]
Facility Limit			$ 30,000,000
Automatic renewal period			1 year
Short-term debt			$ 0
Credit Facilities, Maturing in May 2018 with 1 year Automatic Renewals through 2024 | Dominion Solar Projects III, Inc
Debt Instrument [Line Items]
Facility Limit			$ 25,000,000
Automatic renewal period			1 year
Short-term debt			$ 0
Term Loan Credit Agreement [Member]
Debt Instrument [Line Items]
Credit facility, outstanding amount	$ 500,000,000	$ 950,000,000
Duration of credit facilities	364 days	364 days
Letter of Credit | Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Facility Limit			1,500,000,000		$ 21,000,000
Credit facility, outstanding amount			21,000,000
Letter of Credit | Dominion Energy Midstream Partners, LP
Debt Instrument [Line Items]
Facility Limit						$ 250,000,000
Letter of Credit | Six Billion Joint Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit			2,000,000,000
Letter of Credit | Six Billion Joint Revolving Credit Facility | Virginia Electric and Power Company
Debt Instrument [Line Items]
Facility Limit			$ 2,000,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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]	A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy 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 Energy. This credit facility matures in March 2023 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.
[3]	The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Virginia Power was $1.5 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 Energy. This credit facility matures in March 2023 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.

Short-Term Debt and Credit Ag_4

Short-Term Debt and Credit Agreements (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Detail) - USD ($)		Dec. 31, 2018		Dec. 31, 2017
Line of Credit Facility [Line Items]
Facility Limit		$ 6,000,000,000	[1]	$ 5,500,000,000
Outstanding Commercial Paper	[2]	324,000,000	[1]	3,298,000,000
Outstanding Letters of Credit		88,000,000	[1]	76,000,000
Facility capacity available		5,588,000,000	[1]	2,126,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit		6,000,000,000	[3]	5,500,000,000
Outstanding Commercial Paper	[4]	314,000,000	[3]	542,000,000
Outstanding Letters of Credit	[3]	16,000,000
Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit		1,500,000,000	[5]	1,500,000,000
Outstanding Commercial Paper	[6]	$ 10,000,000	[5]	629,000,000
Previous Credit Facility Five Billion [Member]
Line of Credit Facility [Line Items]
Facility Limit	[7]			5,000,000,000
Outstanding Commercial Paper	[2],[7]			3,298,000,000
Facility capacity available	[7]			1,702,000,000
Previous Credit Facility Five Billion [Member] | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	[8]			5,000,000,000
Outstanding Commercial Paper	[4],[8]			542,000,000
Previous Credit Facility Five Hundred Million [Member]
Line of Credit Facility [Line Items]
Facility Limit	[7]			500,000,000
Outstanding Letters of Credit	[7]			76,000,000
Facility capacity available	[7]			424,000,000
Previous Credit Facility Five Hundred Million [Member] | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	[8]			500,000,000
Previous Credit Facility Five Hundred Million [Member] | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	[9]			500,000,000
Previous Credit Facility One Billion [Member] | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	[9]			1,000,000,000
Outstanding Commercial Paper	[6],[9]			$ 629,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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 Energy's credit facilities were 2.93% and 1.61% at December 31, 2018 and 2017, respectively.
[3]	The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Virginia Power was $1.5 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 Energy. This credit facility matures in March 2023 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.
[4]	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.94% and 1.65% at December 31, 2018 and 2017, respectively.
[5]	A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy 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 Energy. This credit facility matures in March 2023 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.
[6]	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 2.58% and 1.57% at December 31, 2018 and 2017, respectively.
[7]	These credit facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The facilities were scheduled to mature in April 2020 and were 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.
[8]	These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. The full amount of the facilities was available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. These facilities were scheduled to mature in April 2020 and were 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.
[9]	These facilities were replaced in March 2018 with a $6.0 billion joint revolving credit facility. A maximum of a combined $1.5 billion of the facilities was available to Dominion Energy Gas, assuming adequate capacity was available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. These credit facilities were scheduled to mature in April 2020 and were 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.

Short-Term Debt and Credit Ag_5

Short-Term Debt and Credit Agreements (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Parenthetical) (Detail) - USD ($)	Dec. 31, 2018		Oct. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Line of Credit Facility [Line Items]
Facility Limit	$ 6,000,000,000	[1]			$ 5,500,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	6,000,000,000	[2]			5,500,000,000
Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,500,000,000	[3]			$ 1,500,000,000
Six Billion Joint Revolving Credit Facility
Line of Credit Facility [Line Items]
Facility Limit	6,000,000,000			$ 6,000,000,000
Six Billion Joint Revolving Credit Facility | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	1,500,000,000
Credit Facility One Point Five Billion [Member] | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	$ 1,500,000,000
Commercial Paper | 5 Billion, 500 Million And 6 Billion joint Revolving Credit Facilities [Member]
Line of Credit Facility [Line Items]
Weighted-average percentage interest rates	2.93%				1.61%
Commercial Paper | 5 Billion, 500 Million And 6 Billion joint Revolving Credit Facilities [Member] | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Weighted-average percentage interest rates	2.94%				1.65%
Commercial Paper | 1 Billion, 500 Million And 1.5 Billion Joint Revolving Credit Facilities [Member] | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Weighted-average percentage interest rates	2.58%				1.57%
Letter of Credit | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	$ 1,500,000,000		$ 21,000,000
Letter of Credit | Joint Revolving Credit Facility 5 Billion and Joint Revolving Credit Facility 500 Million
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000
Letter of Credit | Joint Revolving Credit Facility 5 Billion and Joint Revolving Credit Facility 500 Million | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000
Letter of Credit | Six Billion Joint Revolving Credit Facility
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000
Letter of Credit | Six Billion Joint Revolving Credit Facility | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000
Line of Credit | Credit Facility One Point Five Billion [Member] | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	$ 750,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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 full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Virginia Power was $1.5 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 Energy. This credit facility matures in March 2023 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.
[3]	A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy 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 Energy. This credit facility matures in March 2023 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.

Long-Term Debt (Total Long Term

Long-Term Debt (Total Long Term Debt) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Securities due within one year	[1],[2]	$ (3,624)	$ (3,078)
Unamortized discount and debt issuance costs		(248)	(245)
Dominion Energy, Inc. total principal		35,109	34,293
Fair value hedge valuation	[3]	(20)	(22)
Credit facility borrowings	[4]	(73)
Dominion Energy, Inc. total long-term debt		$ 31,144	30,948
Capital leases, 4.14% to 6.04%, due 2019 to 2029
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	5.99%
Capital leases, 4.14% to 6.04%, due 2019 to 2029		$ 39
Long Term Debt Due Within One Year [Member]
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[1],[2],[5]	3.23%
Credit facility borrowings
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[4],[5]	3.55%
Senior Notes | Variable rates, due 2019 and 2020
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[6]	3.23%
Total principal	[6]	$ 800	800
Senior Notes | 1.5% to 6.4%, due 2018 to 2022
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[6]	2.75%
Total principal	[6]	$ 2,550	5,800
Senior Notes | 2.85% to 7.0%, due 2024 to 2044
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[6]	4.81%
Total principal	[6]	$ 4,849	5,049
Senior Notes | 6.8% and 6.875%, due 2026 and 2027
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[7]	6.81%
Total principal	[7]	$ 89	89
Senior Notes | 5.31% to 6.3%, due 2018
Debt Instrument [Line Items]
Total principal	[8]		120
Senior Notes | 2.98% to 7.20%, due 2024 to 2051
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[8]	4.25%
Total principal	[8]	$ 750	600
Senior Notes | 4.82%, due 2042
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[9]	4.82%
Total principal	[9]	$ 362
Unsecured Junior Subordinated Notes
Debt Instrument [Line Items]
Dominion Energy, Inc. total principal		$ 2,100
Unsecured Junior Subordinated Notes | 2.579% to 4.104%, due 2019 to 2021
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	3.08%
Total principal		$ 2,100	2,100
Unsecured Junior Subordinated Notes | 8.4% due 2031
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	8.40%
Total principal		$ 10	10
Unsecured Junior Subordinated Notes | 5.25% and 5.75%, due 2054 and 2076
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	5.48%
Total principal		$ 1,485	1,485
Unsecured Junior Subordinated Notes | Variable rates, due 2066
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	5.26%
Total principal		$ 422	422
Remarketable Subordinated Notes
Debt Instrument [Line Items]
Dominion Energy, Inc. total principal		$ 1,400
Remarketable Subordinated Notes | 2.0%, due 2021 and 2024
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	2.00%
Total principal		$ 1,400	1,400
Term Loans
Debt Instrument [Line Items]
Dominion Energy, Inc. total principal	[4],[10]	$ 3,882
Term Loans | Term Loans, variable rates, due 2023 and 2024
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[11]	4.85%
Total principal	[11]	$ 582	638
Term Loans | Tax-Exempt Financing, 1.55%, due 2033
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[12]	1.55%
Total principal	[12]	$ 27	27
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Total principal		4,087	3,600
Securities due within one year		(449)
Unamortized discount and debt issuance costs		(29)	(30)
Total long term debt		3,609	3,570
Dominion Energy, Inc. total principal		$ 4,087
Dominion Energy Gas Holdings, LLC | Long Term Debt Due Within One Year [Member]
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	2.50%
Dominion Energy Gas Holdings, LLC | Senior Notes | Unsecured Senior Notes Variable rate, due 2021 [Member]
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	3.39%
Total principal		$ 500
Dominion Energy Gas Holdings, LLC | Senior Notes | 2.5% to 3.55%, due 2019 to 2023
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	2.90%
Total principal		$ 1,800	1,800
Dominion Energy Gas Holdings, LLC | Senior Notes | 3.317% to 4.8%, due 2024 to 2044
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[13]	4.12%
Total principal	[13]	$ 1,787	1,800
Virginia Electric and Power Company
Debt Instrument [Line Items]
Total principal		11,754	11,418
Securities due within one year		(350)	(850)
Unamortized discount and debt issuance costs		(83)	(72)
Total long term debt		11,321	10,496
Dominion Energy, Inc. total principal		$ 11,754
Virginia Electric and Power Company | Long Term Debt Due Within One Year [Member]
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	5.00%
Virginia Electric and Power Company | Senior Notes | 1.2% to 5.4%, due 2018 to 2023
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	3.35%
Total principal		$ 1,800	2,650
Virginia Electric and Power Company | Senior Notes | 2.95% to 8.875%, due 2024 to 2048
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5]	4.61%
Total principal		$ 9,290	7,990
Virginia Electric and Power Company | Tax Exempt Financing | Utility Tax Exempt Loan Variable Rate Due 2024 To 2027 [Member]
Debt Instrument [Line Items]
Total principal	[14]		100
Virginia Electric and Power Company | Tax Exempt Financing | 1.75% to 5.6%, due 2023 to 2041
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[14]	2.18%
Total principal	[14]	$ 664	678
Dominion Energy Midstream Partners, LP | Senior Notes | Unsecured Senior and Medium Term Notes, 5.83% and 6.48%, due 2018
Debt Instrument [Line Items]
Total principal	[15]		255
Dominion Energy Midstream Partners, LP | Senior Notes | Unsecured Senior Notes, 3.53% to 4.875%, due 2028 to 2041
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[5],[15]	4.23%
Total principal	[15]	$ 430	180
Dominion Energy Midstream Partners, LP | Term Loans | Term Loan Variable Rate Due 2019 and 2021
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[4],[5],[16]	4.13%
Total principal	[4],[16]	$ 3,300	$ 300
Dominion Energy Midstream Partners, LP | Term Loans | Revolving Credit Agreement Variable Rates Due 2021
Debt Instrument [Line Items]
2018 Weighted- average Coupon (percentage)	[4],[5]	3.55%
Total principal	[4]	$ 73
[1]	2017 excludes $250 million of Dominion Energy Questar Pipeline's senior notes that matured in February 2018 using proceeds from the January 2018 issuance, through private placements, of $100 million and $150 million of senior notes that mature in 2028 and 2038, respectively.
[2]	Includes $20 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc.
[3]	Represents the valuation of certain fair value hedges associated with Dominion Energy's fixed rate debt.
[4]	In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy's Consolidated Balance Sheets at December 31, 2018.
[5]	Represents weighted-average coupon rates for debt outstanding as of December 31, 2018.
[6]	In November and December 2018, Dominion Energy redeemed certain senior notes prior to their stated maturity. See below for a discussion of the senior note redemptions.
[7]	Represents debt assumed by Dominion Energy from the merger of its former CNG subsidiary.
[8]	Represents debt obligations of Questar Gas. See Note 3 for more information.
[9]	Represents debt obligations of Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar's interest in certain merchant solar facilities.
[10]	Excludes mandatory prepayments associated with SBL Holdco and Dominion Solar Projects III, Inc. based on cash flows in excess of debt service. At December 31, 2018, $20 million of estimated mandatory prepayments due within one year were included in securities due within one year in Dominion Energy's Consolidated Balance Sheets.
[11]	Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt is nonrecourse to Dominion Energy and is secured by SBL Holdco and Dominion Solar Projects III, Inc.'s interest in certain merchant solar facilities.
[12]	Represents debt obligations of a DGI subsidiary.
[13]	Amount includes foreign currency remeasurement adjustments.
[14]	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. In March 2018, Virginia Power redeemed certain variable rate tax-exempt financings supported by its $100 million credit facility and terminated the facility. In December 2018, Virginia Power redeemed its $14 million Economic Development Authority of the County of Chesterfield Solid Waste and Sewage Disposal Revenue Bonds due in 2031.
[15]	Represents debt obligations of Dominion Energy Questar Pipeline. See Note 3 for more information.
[16]	Includes debt obligations of Cove Point that are secured by Dominion Energy's common equity interest in Cove Point.

Long-Term Debt (Total Long Te_2

Long-Term Debt (Total Long Term Debt) (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Feb. 28, 2019	Feb. 28, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Repayment of Debt			$ 5,682	$ 1,572	$ 1,610
Term Loans
Debt Instrument [Line Items]
Estimated mandatory prepayments due within one year			20
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Repayment of Debt					400
Virginia Electric and Power Company
Debt Instrument [Line Items]
Repayment of Debt			$ 964	$ 681	$ 517
Dominion Energy Midstream Partners, LP
Debt Instrument [Line Items]
Repayment of Debt		$ 250
Dominion Energy Midstream Partners, LP | Subsequent Event
Debt Instrument [Line Items]
Repayment of outstanding credit facility balance	$ 73
2.5% to 3.55%, due 2019 to 2023 | Dominion Energy Gas Holdings, LLC | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			2.50%
2.5% to 3.55%, due 2019 to 2023 | Dominion Energy Gas Holdings, LLC | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			3.55%
3.317% to 4.8%, due 2024 to 2044 | Dominion Energy Gas Holdings, LLC | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			3.317%
3.317% to 4.8%, due 2024 to 2044 | Dominion Energy Gas Holdings, LLC | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			4.80%
1.2% to 5.4%, due 2018 to 2023 | Virginia Electric and Power Company | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			1.20%
1.2% to 5.4%, due 2018 to 2023 | Virginia Electric and Power Company | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			5.40%
2.95% to 8.875%, due 2024 to 2048 | Virginia Electric and Power Company | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			2.95%
2.95% to 8.875%, due 2024 to 2048 | Virginia Electric and Power Company | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			8.875%
1.75% to 5.6%, due 2023 to 2041 | Virginia Electric and Power Company | Tax Exempt Financing | Minimum
Debt Instrument [Line Items]
Interest rate			1.75%
1.75% to 5.6%, due 2023 to 2041 | Virginia Electric and Power Company | Tax Exempt Financing | Maximum
Debt Instrument [Line Items]
Interest rate			5.60%
1.5% to 6.4%, due 2018 to 2022 | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			1.50%
1.5% to 6.4%, due 2018 to 2022 | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			6.40%
2.85% to 7.0%, due 2024 to 2044 | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			2.85%
2.85% to 7.0%, due 2024 to 2044 | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			7.00%
2.579% to 4.104%, due 2019 to 2021 | Unsecured Junior Subordinated Notes | Minimum
Debt Instrument [Line Items]
Interest rate			2.579%
2.579% to 4.104%, due 2019 to 2021 | Unsecured Junior Subordinated Notes | Maximum
Debt Instrument [Line Items]
Interest rate			4.104%
8.4% due 2031 | Unsecured Junior Subordinated Notes
Debt Instrument [Line Items]
Interest rate			8.40%
5.25% and 5.75%, due 2054 and 2076 | Unsecured Junior Subordinated Notes | Minimum
Debt Instrument [Line Items]
Interest rate			5.25%
5.25% and 5.75%, due 2054 and 2076 | Unsecured Junior Subordinated Notes | Maximum
Debt Instrument [Line Items]
Interest rate			5.75%
2.0%, due 2021 and 2024 | Remarketable Subordinated Notes
Debt Instrument [Line Items]
Interest rate			2.00%
6.8% and 6.875%, due 2026 and 2027 | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			6.80%
6.8% and 6.875%, due 2026 and 2027 | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			6.875%
5.31% to 6.3%, due 2018 | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			5.31%
5.31% to 6.3%, due 2018 | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			6.30%
2.98% to 7.20%, due 2024 to 2051 | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			2.98%
2.98% to 7.20%, due 2024 to 2051 | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			7.20%
4.82%, due 2042 | Senior Notes
Debt Instrument [Line Items]
Interest rate			4.82%
Tax-Exempt Financing, 1.55%, due 2033 | Term Loans
Debt Instrument [Line Items]
Interest rate			1.55%
Capital leases, 4.14% to 6.04%, due 2019 to 2029 | Minimum
Debt Instrument [Line Items]
Interest rate			4.14%
Capital leases, 4.14% to 6.04%, due 2019 to 2029 | Maximum
Debt Instrument [Line Items]
Interest rate			6.04%
Unsecured Senior and Medium Term Notes, 5.83% and 6.48%, due 2018 | Dominion Energy Midstream Partners, LP | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			5.83%
Unsecured Senior and Medium Term Notes, 5.83% and 6.48%, due 2018 | Dominion Energy Midstream Partners, LP | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			6.48%
Unsecured Senior Notes, 3.53% to 4.875%, due 2028 to 2041 | Dominion Energy Midstream Partners, LP | Senior Notes | Minimum
Debt Instrument [Line Items]
Interest rate			3.53%
Unsecured Senior Notes, 3.53% to 4.875%, due 2028 to 2041 | Dominion Energy Midstream Partners, LP | Senior Notes | Maximum
Debt Instrument [Line Items]
Interest rate			4.875%
3.53% Due 2028 | Dominion Energy Midstream Partners, LP | Private Placement
Debt Instrument [Line Items]
Repayment of Debt		100
3.91% Due 2038 | Dominion Energy Midstream Partners, LP | Private Placement
Debt Instrument [Line Items]
Repayment of Debt		$ 150
Variable Rate Term Loan | Dominion Energy Midstream Partners, LP | Subsequent Event
Debt Instrument [Line Items]
Repayment of Debt	$ 300
Economic Development Authority of the County of Chesterfield Solid Waste and Sewage Disposal Revenue Bonds due in 2031 | Virginia Electric and Power Company
Debt Instrument [Line Items]
Debt, amount redeemed			$ 14

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) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
2,019		$ 3,607
2,020		2,054
2,021		5,279
2,022		1,556
2,023		1,682
Thereafter		20,931
Total		$ 35,109	$ 34,293
Weighted- average Coupon, 2019		3.23%
Weighted- average Coupon, 2020		2.80%
Weighted- average Coupon, 2021		3.64%
Weighted- average Coupon, 2022		3.02%
Weighted- average Coupon, 2023		3.41%
Weighted- average Coupon, Thereafter		4.51%
Unsecured Senior Notes
Debt Instrument [Line Items]
2,019		$ 2,700
2,020		1,000
2,021		900
2,022		1,500
2,023		1,350
Thereafter		17,195
Total		24,645
Tax-Exempt Financings
Debt Instrument [Line Items]
2,023		40
Thereafter		651
Total		691
Term Loans
Debt Instrument [Line Items]
2,019	[1],[2]	336
2,020	[1],[2]	35
2,021	[1],[2]	3,035
2,022	[1],[2]	34
2,023	[1],[2]	273
Thereafter	[1],[2]	169
Total	[1],[2]	3,882
Credit facility borrowings
Debt Instrument [Line Items]
2,021	[2]	73
Total	[2]	73
Secured Senior Notes
Debt Instrument [Line Items]
2,019		17
2,020		15
2,021		17
2,022		19
2,023		16
Thereafter		278
Total		362
Unsecured Junior Subordinated Notes Payable to Affiliated Trusts
Debt Instrument [Line Items]
Thereafter		10
Total		10
Unsecured Junior Subordinated Notes
Debt Instrument [Line Items]
2,019		550
2,020		1,000
2,021		550
Total		2,100
Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Thereafter		1,907
Total		1,907
Remarketable Subordinated Notes
Debt Instrument [Line Items]
2,021		700
Thereafter		700
Total		1,400
Capital Lease Obligations [Member]
Debt Instrument [Line Items]
2,019		4
2,020		4
2,021		4
2,022		3
2,023		3
Thereafter		21
Total		39
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
2,019		450
2,020		700
2,021		500
2,023		650
Thereafter		1,787
Total		$ 4,087
Weighted- average Coupon, 2019		2.50%
Weighted- average Coupon, 2020		2.80%
Weighted- average Coupon, 2021		3.39%
Weighted- average Coupon, 2023		3.29%
Weighted- average Coupon, Thereafter		4.12%
Virginia Electric and Power Company
Debt Instrument [Line Items]
2,019		$ 350
2,022		750
2,023		740
Thereafter		9,914
Total		$ 11,754
Weighted- average Coupon, 2019		5.00%
Weighted- average Coupon, 2022		3.15%
Weighted- average Coupon, 2023		2.87%
Weighted- average Coupon, Thereafter		4.45%
Virginia Electric and Power Company | Unsecured Senior Notes
Debt Instrument [Line Items]
2,019		$ 350
2,022		750
2,023		700
Thereafter		9,290
Total		11,090
Virginia Electric and Power Company | Tax-Exempt Financings
Debt Instrument [Line Items]
2,023		40
Thereafter		624
Total		$ 664
[1]	Excludes mandatory prepayments associated with SBL Holdco and Dominion Solar Projects III, Inc. based on cash flows in excess of debt service. At December 31, 2018, $20 million of estimated mandatory prepayments due within one year were included in securities due within one year in Dominion Energy's Consolidated Balance Sheets.
[2]	In February 2019, Dominion Energy Midstream repaid its $300 million variable rate term loan due in December 2019 and terminated the credit facility due in March 2021 subsequent to repaying the $73 million outstanding balance. As such, credit facility borrowings are presented within current liabilities in Dominion Energy's Consolidated Balance Sheets at December 31, 2018.

Long-Term Debt (Based on Stat_2

Long-Term Debt (Based on Stated Maturity Dates Rather than Early Redemption Dates that Could be Elected by Instrument Holders) (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Feb. 28, 2019	Feb. 28, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Repayment of Debt			$ 5,682	$ 1,572	$ 1,610
Term Loans
Debt Instrument [Line Items]
Estimated mandatory prepayments due within one year			$ 20
Dominion Energy Midstream Partners, LP
Debt Instrument [Line Items]
Repayment of Debt		$ 250
Dominion Energy Midstream Partners, LP | Subsequent Event
Debt Instrument [Line Items]
Repayment of outstanding credit facility balance	$ 73
Variable Rate Term Loan | Dominion Energy Midstream Partners, LP | Subsequent Event
Debt Instrument [Line Items]
Repayment of Debt	$ 300

Long-Term Debt (Narrative) (Det

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

Oct. 01, 2024

Aug. 15, 2016

Aug. 31, 2019

Jul. 31, 2017

Jul. 31, 2016

Apr. 30, 2016

Oct. 31, 2014

Sep. 30, 2011

Sep. 30, 2006

Jun. 30, 2006

Dec. 31, 2018

May 31, 2017

Aug. 31, 2016

Jun. 29, 2016

May 31, 2016

Mar. 31, 2016

Jul. 31, 2014

Jun. 30, 2013

Debt Instrument [Line Items]

Aggregate outstanding principal of senior notes

$ 2,200,000,000

Aggregate redemption price paid

2,200,000,000

Make-whole premium

$ 34,000,000

Period of deferral

10 years

Period for consideration of proceeds (days)

180 days

365 days

Interest in RSN issued by Dominion (percentage)

5.00%

Common Stock

Debt Instrument [Line Items]

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

$ 50

Shares reserved and available for issuance

23,100,000

Capital Unit, Class A

Debt Instrument [Line Items]

Principal amount of notes

$ 1,400,000,000

Payment percentage rate on Equity Units

6.75%

6.375%

6.125%

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

$ 50

Issuance of common stock (in shares)

28,000,000

[1]

12,500,000

Capital Unit, Class B

Debt Instrument [Line Items]

Payment percentage rate on Equity Units

6.00%

Scenario, Forecast | Maximum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts

18,900,000

Scenario, Forecast | Minimum

Debt Instrument [Line Items]

Shares to be issued under purchase contracts

15,100,000

Senior Note Redemptions [Member]

Debt Instrument [Line Items]

Interest expense

$ 69,000,000

Senior Note Redemptions [Member] | Series A 4.45% Senior Notes Due 2021 [Member]

Debt Instrument [Line Items]

Interest rate (percentage)

4.45%

Senior Note Redemptions [Member] | Series B 2.50% Senior Notes Due 2019 [Member]

Debt Instrument [Line Items]

Interest rate (percentage)

2.50%

Senior Note Redemptions [Member] | Series C 3.625% Senior Notes Due 2024 [Member]

Debt Instrument [Line Items]

Interest rate (percentage)

3.625%

June 2006 and September 2006 hybrids | Unsecured Junior Subordinated Notes | Maximum

Debt Instrument [Line Items]

Amount purchased and cancelled

$ 200,000,000

July 2016 Hybrids | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Interest rate (percentage)

5.25%

Principal amount of notes

$ 800,000,000

Remarketable Subordinated Notes | Capital Unit, Class A

Debt Instrument [Line Items]

Interest rate (percentage)

2.00%

[1],[2]

1.50%

1.07%

Principal amount of notes

$ 1,400,000,000

[1]

$ 1,000,000,000

$ 550,000,000

$ 1,000,000,000

$ 550,000,000

Issuance of common stock (in shares)

12,500,000

8,500,000

8,500,000

Remarketable Subordinated Notes | Capital Unit, Class B

Debt Instrument [Line Items]

Interest rate (percentage)

1.18%

Principal amount of notes

$ 550,000,000

$ 550,000,000

Series A Junior Subordinated Notes | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Interest rate (percentage)

2.579%

4.104%

Series B Junior Subordinated Notes | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Interest rate (percentage)

2.962%

Remarketable Subordinated Notes, 2016 Series A-1, due August 15, 2021

Debt Instrument [Line Items]

Interest in RSN issued by Dominion (percentage)

2.50%

Remarketable Subordinated Notes, 2016 Series A-1, due August 15, 2021 | Capital Unit, Class A

Debt Instrument [Line Items]

Principal amount of notes

700,000,000

Remarketable Subordinated Notes, 2016 Series A-2, due August 15, 2024

Debt Instrument [Line Items]

Interest in RSN issued by Dominion (percentage)

2.50%

Remarketable Subordinated Notes, 2016 Series A-2, due August 15, 2024 | Capital Unit, Class A

Debt Instrument [Line Items]

Principal amount of notes

$ 700,000,000

June 2006 hybrids

Debt Instrument [Line Items]

Aggregate redemption price paid

$ 38,000,000

Interest rate (percentage)

7.50%

Junior subordinated notes

$ 300,000,000

June 2006 hybrids | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Amount purchased and cancelled

$ 125,000,000

June 2006 hybrids | LIBOR [Member]

Debt Instrument [Line Items]

Spread on variable percentage rate

2.825%

September 2006 hybrids

Debt Instrument [Line Items]

Aggregate redemption price paid

$ 4,000,000

Junior subordinated notes

$ 500,000,000

September 2006 hybrids | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Amount purchased and cancelled

$ 74,000,000

September 2006 hybrids | LIBOR [Member]

Debt Instrument [Line Items]

Spread on variable percentage rate

2.30%

October 2014 Hybrids [Member] | Unsecured Junior Subordinated Notes

Debt Instrument [Line Items]

Interest rate (percentage)

5.75%

Principal amount of notes

$ 685,000,000

October 2014 Hybrids [Member] | LIBOR [Member] | Unsecured Junior Subordinated Notes | Scenario, Forecast

Debt Instrument [Line Items]

Spread on variable percentage rate

3.057%

[1]

The maturity dates of the $700 million Series A-1 RSNs and $700 million Series A-2 RSNs are August 15, 2021 and August 15, 2024, respectively.

[2]

Annual interest rate applies to each of the Series A-1 RSNs and Series A-2 RSNs.

Long-Term Debt Long Term Debt (

Long-Term Debt Long Term Debt (Schedule of Equity Units) (Detail) - USD ($) shares in Millions

Aug. 15, 2016

Jul. 31, 2017

Jul. 31, 2016

Apr. 30, 2016

Dec. 31, 2018

Dec. 31, 2017

May 31, 2017

Aug. 31, 2016

Mar. 31, 2016

Jul. 31, 2014

Jun. 30, 2013

Capital Unit [Line Items]

Stock Purchase Contract Liability

$ 47,000,000

$ 111,000,000

Capital Unit, Class A

Capital Unit [Line Items]

Units Issued

28

[1]

12.5

Total Net Proceeds

[1]

$ 1,374,800,000

Total Long-term Debt

$ 1,400,000,000

Stock Purchase Contract Annual Rate (Percentage)

[1]

4.75%

Stock Purchase Contract Liability

[1],[2]

$ 190,600,000

Stock Purchase Settlement Date

[1]

Aug. 15, 2019

Capital Unit, Class A | Remarketable Subordinated Notes

Capital Unit [Line Items]

Units Issued

12.5

8.5

8.5

Total Long-term Debt

$ 1,400,000,000

[1]

$ 1,000,000,000

$ 550,000,000

$ 1,000,000,000

$ 550,000,000

RSN Annual Interest Rate

2.00%

[1],[3]

1.50%

1.07%

[1]

The maturity dates of the $700 million Series A-1 RSNs and $700 million Series A-2 RSNs are August 15, 2021 and August 15, 2024, respectively.

[2]

Payments of $64 million and $101 million were made in 2018 and 2017, respectively, including payments for the remarketed 2014 Series A notes. The stock purchase contract liability was $47 million and $111 million at December 31, 2018 and 2017, respectively.

[3]

Annual interest rate applies to each of the Series A-1 RSNs and Series A-2 RSNs.

Long-Term Debt Long Term Debt_2

Long-Term Debt Long Term Debt (Schedule of Equity Units) (Parenthetical) (Detail) - USD ($)		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Aug. 31, 2016	Aug. 15, 2016
Capital Unit [Line Items]
Stock Purchase Contract Liability		$ 47,000,000	$ 111,000,000
Total payments		$ 64,000,000	$ 101,000,000
Capital Unit, Class A
Capital Unit [Line Items]
Stock Purchase Contract Liability	[1],[2]				$ 190,600,000
Total Long-term Debt				$ 1,400,000,000
Capital Unit, Class A | Remarketable Subordinated Notes, 2016 Series A-1, due August 15, 2021
Capital Unit [Line Items]
Total Long-term Debt					700,000,000
Capital Unit, Class A | Remarketable Subordinated Notes, 2016 Series A-2, due August 15, 2024
Capital Unit [Line Items]
Total Long-term Debt					$ 700,000,000
[1]	Payments of $64 million and $101 million were made in 2018 and 2017, respectively, including payments for the remarketed 2014 Series A notes. The stock purchase contract liability was $47 million and $111 million at December 31, 2018 and 2017, respectively.
[2]	The maturity dates of the $700 million Series A-1 RSNs and $700 million Series A-2 RSNs are August 15, 2021 and August 15, 2024, respectively.

Preferred Stock (Narrative) (De

Preferred Stock (Narrative) (Detail) - $ / shares	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Preferred stock shares authorized	20,000,000	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	10,000,000
Preferred stock shares issued	0	0
Preferred stock shares outstanding	0	0
Liquidation preference (in dollars per share)	$ 100

Equity (Narrative) (Detail)

Equity (Narrative) (Detail)	Aug. 15, 2016shares	[1]	Jan. 31, 2019USD ($)shares	Dec. 31, 2018USD ($)shares	Jun. 30, 2018USD ($)shares	May 31, 2018	Apr. 30, 2018shares	Feb. 28, 2018USD ($)Agreement	Jan. 31, 2018USD ($)Performance_Factorshares	Jul. 31, 2017USD ($)shares	Jun. 30, 2017USD ($)Agreement	Jul. 31, 2016shares	Apr. 30, 2016USD ($)shares	Apr. 30, 2018shares	Dec. 31, 2018USD ($)shares	Dec. 31, 2019shares	Dec. 31, 2018USD ($)Performance_Factorshares	Dec. 31, 2017USD ($)shares	Dec. 31, 2016USD ($)shares	Sep. 30, 2015USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock																	$ 2,461,000,000	$ 1,302,000,000	$ 2,152,000,000
Common stock, shares outstanding | shares				681,000,000											681,000,000		681,000,000	645,000,000
Issuance of common stock (in shares)																	$ 2,461,000,000	$ 1,302,000,000	2,152,000,000
Net proceeds from issuance of Dominion Midstream common units																	$ 4,000,000	18,000,000	482,000,000
Net proceeds from issuance of Dominion Midstream convertible preferred units																			490,000,000
Conversion basis				1											1		1
Subordinated unit conversion						1
Number of shares received | shares					26,700,000
Increase (decrease) Non-controlling interest					$ 375,000,000
Compensation cost related to stock-based compensation																	$ 48,000,000	45,000,000	33,000,000
Tax benefit from stock awards and stock options exercised																	$ 12,000,000	16,000,000	11,000,000
Vesting period																	3 years
Subsequent Event
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares of common stock issued in acquisition | shares			22,500,000
Shares of common stock issued in acquisition, value			$ 1,600,000,000
Cash Based Performance Grant | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cash-based performance grants minimum percentage																	0.00%
Cash-based performance grants maximum percentage																	200.00%
February 2016 Cash Based Performance Grant | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of performance metrics achieved | Performance_Factor									2
Expected award under grant									$ 12,000,000
February 2017 Cash Based Performance Grant [Member] | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of performance metrics achieved | Performance_Factor																	2
February 2017 Cash Based Performance Grant [Member] | Officer | Two-year grant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Targeted amount of the grant				$ 13,000,000											$ 13,000,000		$ 13,000,000
Liability accrued for award				13,000,000											13,000,000		13,000,000
February 2017 Cash Based Performance Grant [Member] | Officer | Three-year grant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Targeted amount of the grant				14,000,000											14,000,000		14,000,000
Liability accrued for award				10,000,000											10,000,000		$ 10,000,000
February 2018 Cash Based Performance Grant [Member] | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of performance metrics achieved | Performance_Factor																	2
February 2018 Cash Based Performance Grant [Member] | Officer | Three-year grant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Targeted amount of the grant				16,000,000											16,000,000		$ 16,000,000
Liability accrued for award				$ 5,000,000											$ 5,000,000		$ 5,000,000
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]
Number of shares for future agreement | shares				76,000,000											76,000,000		76,000,000
Stock Based Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares were available for future grants | shares				22,000,000											22,000,000		22,000,000
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost related to nonvested awards				$ 49,000,000											$ 49,000,000		$ 49,000,000
Fair value of restricted stock awards that vested																	$ 23,000,000	$ 21,000,000	$ 21,000,000
Virginia Electric and Power Company
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock (in shares | shares																	0	0	0
Common stock, shares outstanding | shares				274,723											274,723		274,723	274,723
Repurchase of common stock, shares | shares																	0	0
Virginia Electric and Power Company | Scenario, Forecast
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Repurchase of common stock, shares | shares																0
Dominion Midstream Partners, LP | Limited Partner
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Net proceeds from issuance of Dominion Midstream common units																		$ 18,000,000	$ 482,000,000
Dominion Midstream Partners, LP | Limited Partner | Convertible Preferred Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Net proceeds from issuance of Dominion Midstream convertible preferred units																			$ 490,000,000
Dominion Midstream Partners, LP | Dominion Midstream Limited Partner Common Unit Purchase Program | Limited Partner
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Authorized purchase amount																				$ 50,000,000
Stock repurchase program expiration date																	Sep. 30, 2016
Number of common units purchased | shares																			658,000
Value of common units purchased																			$ 17,000,000
Maximum | Stock Based Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum term of stock based awards																	8 years
Weighted Average | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected weighted-average period recognized for the unrecognized compensation cost																	2 years 1 month 6 days
Noncontrolling Interests
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Increase (decrease) Non-controlling interest					$ (375,000,000)
Goldman Sachs & Co. and Credit Suisse LLC.
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock				$ 1,400,000,000
Issuance of common stock (in shares | shares				22,100,000
Number of shares for future agreement | shares							20,000,000							20,000,000
Capital Unit, Class A
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock										$ 1,000,000,000
Issuance of common stock (in shares | shares	28,000,000									12,500,000
Capital Unit, Class A | Remarketable Subordinated Notes
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock																	$ 1,100,000,000
Issuance of common stock (in shares | shares										12,500,000		8,500,000	8,500,000
Underwritten Public Offering
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock													$ 756,000,000
Issuance of common stock (in shares | shares													10,200,000
Various Programs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock																	$ 2,500,000,000
Issuance of common stock (in shares | shares																	36,000,000
Common stock, shares outstanding | shares				681,000,000											681,000,000		681,000,000
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																	$ 315,000,000
Number of shares issued through Dominion Direct and employee savings plans | shares																	4,500,000
Shelf Registration for Sale of Common Stock through At-the-market Program
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Issuance of common stock									$ 495,000,000						$ 197,000,000
Issuance of common stock (in shares | shares									6,600,000						2,700,000
Number of sales agency agreements | Agreement								6			3
Issuance of common stock (in shares)											$ 0
Fees and commissions paid									$ 5,000,000						$ 2,000,000
Remaining ability to issue stock under the sales agency agreements				$ 801,000,000											$ 801,000,000		$ 801,000,000
Shelf Registration for Sale of Common Stock through At-the-market Program | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Sale of stock authorized amount								$ 1,000,000,000			$ 500,000,000
Underwriting Agreement | Goldman Sachs & Co. and Credit Suisse LLC.
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Option exercised | shares							2,100,000
Underwriting Agreement | Goldman Sachs & Co. and Credit Suisse LLC. | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted for service | shares														3,000,000
[1]	The maturity dates of the $700 million Series A-1 RSNs and $700 million Series A-2 RSNs are August 15, 2021 and August 15, 2024, respectively.

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss)) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI, including noncontrolling interest	$ (1,699)	$ (658)
Less other comprehensive income attributable to noncontrolling interest	1	1
Total AOCI	(1,700)	(659)
Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(234)	(301)
Amount of tax	79	188
Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	2	747
Amount of tax		(419)
Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(1,465)	(1,101)
Amount of tax	519	692
Other Comprehensive Loss From Equity Method Investee
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(2)	(3)
Amount of tax		2
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(12)	62
Virginia Electric and Power Company | Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(13)	(12)
Amount of tax	4	8
Virginia Electric and Power Company | Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	1	74
Amount of tax		(47)
Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(169)	(98)
Dominion Energy Gas Holdings, LLC | Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(25)	(23)
Amount of tax	8	15
Dominion Energy Gas Holdings, LLC | Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total AOCI	(144)	(75)
Amount of tax	$ 56	$ 59

Equity (Schedule of Changes in

Equity (Schedule of Changes in AOCI by Component Net of Tax) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		$ 17,142
Ending balance		20,107	$ 17,142
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		12,224
Ending balance		13,047	12,224
Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(302)	(280)
Other comprehensive income before reclassifications: gains (losses)		30	8
Amounts reclassified from AOCI: (gains) losses	[1]	102	(29)
Net current period other comprehensive income (loss)		132	(21)
Cumulative-effect of changes in accounting principle		(64)
Less other comprehensive income (loss) attributable to noncontrolling interest		1	1
Ending balance		(235)	(302)
Deferred Gains and Losses on Derivatives-Hedging Activities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(12)	(8)
Other comprehensive income before reclassifications: gains (losses)		1	(5)
Amounts reclassified from AOCI: (gains) losses	[1]	1	1
Net current period other comprehensive income (loss)		2	(4)
Cumulative-effect of changes in accounting principle		(3)
Ending balance		(13)	(12)
Deferred Gains and Losses on Derivatives-Hedging Activities | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(23)	(24)
Other comprehensive income before reclassifications: gains (losses)		(17)	5
Amounts reclassified from AOCI: (gains) losses	[1]	20	(4)
Net current period other comprehensive income (loss)		3	1
Cumulative-effect of changes in accounting principle		(5)
Ending balance		(25)	(23)
Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		747	569
Other comprehensive income before reclassifications: gains (losses)		(18)	215
Amounts reclassified from AOCI: (gains) losses	[1]	5	(37)
Net current period other comprehensive income (loss)		(13)	178
Cumulative-effect of changes in accounting principle		(732)
Ending balance		2	747
Unrealized Gains and Losses on Investment Securities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		74	54
Other comprehensive income before reclassifications: gains (losses)			24
Amounts reclassified from AOCI: (gains) losses	[1]		(4)
Net current period other comprehensive income (loss)			20
Cumulative-effect of changes in accounting principle		(73)
Ending balance		1	74
Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(1,101)	(1,082)
Other comprehensive income before reclassifications: gains (losses)		(215)	(69)
Amounts reclassified from AOCI: (gains) losses	[1]	78	50
Net current period other comprehensive income (loss)		(137)	(19)
Cumulative-effect of changes in accounting principle		(227)
Ending balance		(1,465)	(1,101)
Unrecognized Pension and Other Postretirement Benefit Costs | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(75)	(99)
Other comprehensive income before reclassifications: gains (losses)		(52)	20
Amounts reclassified from AOCI: (gains) losses	[1]	4	4
Net current period other comprehensive income (loss)		(48)	24
Cumulative-effect of changes in accounting principle		(21)
Ending balance		(144)	(75)
Other Comprehensive Loss From Equity Method Investee
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(3)	(6)
Other comprehensive income before reclassifications: gains (losses)		1	3
Net current period other comprehensive income (loss)		1	3
Ending balance		(2)	(3)
Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(659)	(799)
Other comprehensive income before reclassifications: gains (losses)		(202)	157
Amounts reclassified from AOCI: (gains) losses	[1]	185	(16)
Net current period other comprehensive income (loss)		(17)	141
Cumulative-effect of changes in accounting principle		(1,023)
Less other comprehensive income (loss) attributable to noncontrolling interest		1	1
Ending balance		(1,700)	(659)
Accumulated Other Comprehensive Income (Loss) | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		62	46
Other comprehensive income before reclassifications: gains (losses)		1	19
Amounts reclassified from AOCI: (gains) losses	[1]	1	(3)
Net current period other comprehensive income (loss)		2	16
Cumulative-effect of changes in accounting principle		(76)
Ending balance		(12)	62
Accumulated Other Comprehensive Income (Loss) | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(98)	(123)
Other comprehensive income before reclassifications: gains (losses)		(69)	25
Amounts reclassified from AOCI: (gains) losses	[1]	24
Net current period other comprehensive income (loss)		(45)	25
Cumulative-effect of changes in accounting principle		(26)
Ending balance		$ (169)	$ (98)
[1]	See table below for details about these reclassifications.

Equity (Schedule of Reclassific

Equity (Schedule of Reclassifications out of AOCI by Component Net of Tax) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Electric fuel and other energy related purchases		$ (2,814)	$ (2,301)	$ (2,333)
Purchased gas		(645)	(701)	(459)
Interest and related charges		(1,493)	(1,205)	(1,010)
Other income	[1]	1,021	358	429
Income from operations before income tax expense		3,129	3,090	2,867
Income tax expense		(580)	30	(655)
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Electric fuel and other energy related purchases	[2]	(2,318)	(1,909)	(1,973)
Interest and related charges	[2]	(511)	(494)	(461)
Other income		22	76	56
Income from operations before income tax expense		1,582	2,314	1,945
Income tax expense		(300)	(774)	(727)
Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Purchased gas	[3]	(40)	(132)	(109)
Interest and related charges	[3]	(105)	(97)	(94)
Other income		133	104	87
Income from operations before income tax expense		387	666	607
Income tax expense		(86)	(51)	$ (215)
Deferred (gains) and losses on derivatives-hedging activities: | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Income from operations before income tax expense		137	(47)
Income tax expense		(35)	18
Income from continuing operations including noncontrolling interests		102	(29)
Deferred (gains) and losses on derivatives-hedging activities: | Commodity | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue		90	(81)
Electric fuel and other energy related purchases		(14)
Purchased gas			2
Deferred (gains) and losses on derivatives-hedging activities: | Interest rate | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Interest and related charges		48	52
Deferred (gains) and losses on derivatives-hedging activities: | Foreign currency | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		13	(20)
Deferred (gains) and losses on derivatives-hedging activities: | Virginia Electric and Power Company | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Income from operations before income tax expense		1	1
Income from continuing operations including noncontrolling interests		1	1
Deferred (gains) and losses on derivatives-hedging activities: | Virginia Electric and Power Company | Interest rate | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Interest and related charges		1	1
Deferred (gains) and losses on derivatives-hedging activities: | Dominion Energy Gas Holdings, LLC | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Income from operations before income tax expense		27	(7)
Income tax expense		(7)	3
Income from continuing operations including noncontrolling interests		20	(4)
Deferred (gains) and losses on derivatives-hedging activities: | Dominion Energy Gas Holdings, LLC | Commodity | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue		8	8
Deferred (gains) and losses on derivatives-hedging activities: | Dominion Energy Gas Holdings, LLC | Interest rate | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Interest and related charges		6	5
Deferred (gains) and losses on derivatives-hedging activities: | Dominion Energy Gas Holdings, LLC | Foreign currency | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		13	(20)
Unrealized (gains) and losses on investment securities: | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Realized (gain) loss on sale of securities		7	(81)
Impairment			23
Income from operations before income tax expense		7	(58)
Income tax expense		(2)	21
Income from continuing operations including noncontrolling interests		5	(37)
Unrealized (gains) and losses on investment securities: | Virginia Electric and Power Company | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Realized (gain) loss on sale of securities			(9)
Impairment			2
Income from operations before income tax expense			(7)
Income tax expense			3
Income from continuing operations including noncontrolling interests			(4)
Unrecognized pension and other postretirement benefit costs: | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		(21)	(21)
Other income		120	103
Unrecognized pension and other postretirement benefit costs, before tax		99	82
Unrecognized pension and other postretirement benefit costs, income tax expense		(21)	(32)
Unrecognized pension and other postretirement benefit costs, net of tax		78	50
Unrecognized pension and other postretirement benefit costs: | Dominion Energy Gas Holdings, LLC | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		6	6
Unrecognized pension and other postretirement benefit costs, before tax		6	6
Unrecognized pension and other postretirement benefit costs, income tax expense		(2)	(2)
Unrecognized pension and other postretirement benefit costs, net of tax		$ 4	$ 4
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.

Equity (Summary of Restricted S

Equity (Summary of Restricted Stock and Goal-Based Stock Activity) (Detail) - Restricted Stock - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested beginning (in shares)	1,043	886	855
Granted (in shares)	534	454	372
Vested (in shares)	(316)	(287)	(301)
Cancelled and forfeited (in shares)	(53)	(10)	(40)
Nonvested ending (in shares)	1,208	1,043	886
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 (in dollars per share)	$ 73.32	$ 71.40	$ 66.16
Granted, Weighted Average Grant Date Fair Value (in dollars per share)	72.92	74.24	71.67
Vested, Weighted Average Grant Date Fair Value (in dollars per share)	73.59	68.90	56.83
Cancelled and forfeited, Weighted Average Grant Date Fair Value (in dollars per share)	74.25	72.37	71.75
Nonvested ending, Weighted Average Grant Date Fair Value (in dollars per share)	$ 73.03	$ 73.32	$ 71.40

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Detail) - USD ($)	Sep. 30, 2017	Jun. 30, 2017	Jan. 31, 2017	Dec. 31, 2017	Mar. 31, 2017	Sep. 30, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2019
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							$ (605,000,000)	$ 1,600,000,000
Expected return on pension and other postretirement plan assets							806,000,000	767,000,000
Accumulated benefit obligation				$ 8,200,000,000			7,800,000,000	8,200,000,000
Contributions to qualified defined benefit pension plans							0
Contributions to qualified defined benefit pension plans in 2019							21,000,000
Contribution to voluntary employees beneficiary association							12,000,000	12,000,000
Defined contribution plan, employer matching contributions							$ 51,000,000	45,000,000	$ 44,000,000
Special Termination Benefits | Organizational Design Initiative
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Organizational design initiative									65,000,000
Organizational design initiative, after tax									40,000,000
Common and Preferred Stocks
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages							28.00%
Non-U.S.Equity
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages							18.00%
Fixed Income
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages							35.00%
Real Estate Funds
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages							3.00%
Other Alternative Investments
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages							16.00%
Scenario, Forecast
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension or other postretirement plan assets to be returned										$ 0
Pension Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							$ (513,000,000)	1,327,000,000
Expected return on pension and other postretirement plan assets							663,000,000	639,000,000	573,000,000
Net periodic benefit cost							25,000,000	7,000,000	$ (25,000,000)
Decrease in accumulated postretirement benefit obligation				75,000,000
Discount rate percentage	4.05%	4.05%	4.51%						4.46%
Contributions to qualified defined benefit pension plans							6,000,000	118,000,000
Other Postretirement Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							(92,000,000)	236,000,000
Expected return on pension and other postretirement plan assets							143,000,000	128,000,000	$ 118,000,000
Net periodic benefit cost							$ (101,000,000)	$ (80,000,000)	$ (49,000,000)
Decrease in accumulated postretirement benefit obligation				$ 2,000,000
Discount rate percentage							3.76%
Discount rate percentage				3.76%				3.76%
Contributions to qualified defined benefit pension plans							$ 12,000,000	$ 13,000,000
Medical Coverage for Local retirees
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Decrease in accumulated postretirement benefit obligation					$ 73,000,000	$ 37,000,000
Discount rate percentage					4.30%	3.71%
Charge recorded from plan amendment and remeasurement						$ 9,000,000
Collective Bargaining Agreement
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Period for experience study of employee demographics									5 years
Net periodic benefit cost								42,000,000
Charge recorded from plan amendment and remeasurement					$ 7,000,000
Charge recorded from plan amendment and remeasurement, after tax					4,000,000
Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase in the pension and postretirement benefit obligations									$ 290,000,000
Collective Bargaining Agreement | Other Postretirement Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase in the pension and postretirement benefit obligations									38,000,000
Dominion Energy Gas Holdings, LLC
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							(129,000,000)	335,000,000
Expected return on pension and other postretirement plan assets							178,000,000	165,000,000
Accumulated benefit obligation				$ 724,000,000			689,000,000	724,000,000
Contributions to qualified defined benefit pension plans							0
Contributions to qualified defined benefit pension plans in 2019							0
Expected contribution to voluntary employees beneficiary association							12,000,000
Defined contribution plan, employer matching contributions							8,000,000	7,000,000	7,000,000
Dominion Energy Gas Holdings, LLC | Other operations and maintenance | Dominion Energy Retiree Health And Welfare Plan [Member] | Multiemployer Plans, Postretirement Benefit
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost							(7,000,000)	(5,000,000)	(4,000,000)
Dominion Energy Gas Holdings, LLC | Special Termination Benefits | Organizational Design Initiative
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Organizational design initiative									8,000,000
Organizational design initiative, after tax									5,000,000
Dominion Energy Gas Holdings, LLC | Scenario, Forecast
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension or other postretirement plan assets to be returned										$ 0
Dominion Energy Gas Holdings, LLC | Pension Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							(113,000,000)	294,000,000
Expected return on pension and other postretirement plan assets							150,000,000	141,000,000	134,000,000
Net periodic benefit cost							$ (84,000,000)	$ (80,000,000)	$ (78,000,000)
Discount rate percentage							3.81%	4.50%	4.99%
Discount rate percentage				3.81%			4.42%	3.81%
Dominion Energy Gas Holdings, LLC | Pension Benefits | Other operations and maintenance
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost							$ (38,000,000)	$ (37,000,000)	$ (45,000,000)
Dominion Energy Gas Holdings, LLC | Other Postretirement Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on plan assets							(16,000,000)	41,000,000
Expected return on pension and other postretirement plan assets							28,000,000	24,000,000	23,000,000
Net periodic benefit cost							$ (14,000,000)	$ (9,000,000)	$ (2,000,000)
Discount rate percentage							3.81%	4.47%	4.93%
Discount rate percentage				3.76%			4.37%	3.76%
Contributions to qualified defined benefit pension plans							$ 12,000,000	$ 12,000,000
Dominion Energy Gas Holdings, LLC | Medical Coverage for Local retirees
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Decrease in accumulated postretirement benefit obligation					61,000,000
Dominion Energy Gas Holdings, LLC | Collective Bargaining Agreement
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Charge recorded from plan amendment and remeasurement					6,000,000
Charge recorded from plan amendment and remeasurement, after tax					$ 4,000,000
Dominion Energy Gas Holdings, LLC | Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase in the pension and postretirement benefit obligations									$ 24,000,000
Dominion Energy Gas Holdings, LLC | Collective Bargaining Agreement | Other Postretirement Benefits
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase in the pension and postretirement benefit obligations									9,000,000
Virginia Electric and Power Company
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined contribution plan, employer matching contributions							20,000,000	19,000,000	19,000,000
Virginia Electric and Power Company | Other operations and maintenance | Dominion Energy Retiree Health And Welfare Plan [Member] | Multiemployer Plans, Postretirement Benefit
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost							(51,000,000)	(42,000,000)	(29,000,000)
Virginia Electric and Power Company | Special Termination Benefits | Organizational Design Initiative
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Organizational design initiative									33,000,000
Organizational design initiative, after tax									20,000,000
Virginia Electric and Power Company | Pension Benefits | Other operations and maintenance
Defined Benefit Plans And Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost							$ 126,000,000	$ 110,000,000	$ 79,000,000

Employee Benefit Plans (Summary

Employee Benefit Plans (Summary of Changes in Pension and Other Postretirement Benefit Plans) (Detail) - USD ($)		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Changes in fair value of plan assets:
Actual return (loss) on plan assets		$ (605,000,000)	$ 1,600,000,000
Employer contributions		0
Dominion Energy Gas Holdings, LLC
Changes in fair value of plan assets:
Actual return (loss) on plan assets		(129,000,000)	335,000,000
Employer contributions		0
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year		9,052,000,000	8,132,000,000
Service cost		157,000,000	138,000,000	$ 118,000,000
Interest cost		337,000,000	345,000,000	317,000,000
Benefits paid		(358,000,000)	(323,000,000)
Actuarial (gains) losses during the year		(688,000,000)	830,000,000
Plan amendments	[1]		5,000,000
Settlements and curtailments	[2]		(75,000,000)
Benefit obligation at end of year		8,500,000,000	9,052,000,000	8,132,000,000
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		8,062,000,000	7,016,000,000
Actual return (loss) on plan assets		(513,000,000)	1,327,000,000
Employer contributions		6,000,000	118,000,000
Benefits paid		(358,000,000)	(323,000,000)
Settlements	[2]		(76,000,000)
Fair value of plan assets at end of year		7,197,000,000	8,062,000,000	7,016,000,000
Funded status at end of year		(1,303,000,000)	(990,000,000)
Noncurrent pension and other postretirement benefit assets		1,003,000,000	1,117,000,000
Other current liabilities		(34,000,000)	(8,000,000)
Noncurrent pension and other postretirement benefit liabilities		(2,272,000,000)	(2,099,000,000)
Net amount recognized		$ (1,303,000,000)	$ (990,000,000)
Significant assumptions used to determine benefit obligations
Weighted average rate of increase for compensation		4.32%	4.09%
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year		$ 773,000,000	$ 683,000,000
Service cost		18,000,000	15,000,000	13,000,000
Interest cost		29,000,000	30,000,000	30,000,000
Benefits paid		(34,000,000)	(33,000,000)
Actuarial (gains) losses during the year		(56,000,000)	78,000,000
Benefit obligation at end of year		730,000,000	773,000,000	683,000,000
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		1,803,000,000	1,542,000,000
Actual return (loss) on plan assets		(113,000,000)	294,000,000
Benefits paid		(34,000,000)	(33,000,000)
Fair value of plan assets at end of year		1,656,000,000	1,803,000,000	1,542,000,000
Funded status at end of year		926,000,000	1,030,000,000
Noncurrent pension and other postretirement benefit assets		926,000,000	1,030,000,000
Net amount recognized		$ 926,000,000	$ 1,030,000,000
Significant assumptions used to determine benefit obligations
Discount rate		4.42%	3.81%
Weighted average rate of increase for compensation		4.55%	4.11%
Pension Benefits | Minimum
Significant assumptions used to determine benefit obligations
Discount rate		4.42%	3.80%
Pension Benefits | Maximum
Significant assumptions used to determine benefit obligations
Discount rate		4.43%	3.81%
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year		$ 1,529,000,000	$ 1,478,000,000
Service cost		27,000,000	26,000,000	31,000,000
Interest cost		56,000,000	60,000,000	65,000,000
Benefits paid		(87,000,000)	(83,000,000)
Actuarial (gains) losses during the year		(158,000,000)	119,000,000
Plan amendments	[1]	(4,000,000)	(73,000,000)
Settlements and curtailments	[2]		2,000,000
Benefit obligation at end of year		1,363,000,000	1,529,000,000	1,478,000,000
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		1,729,000,000	1,512,000,000
Actual return (loss) on plan assets		(92,000,000)	236,000,000
Employer contributions		12,000,000	13,000,000
Benefits paid		(68,000,000)	(32,000,000)
Fair value of plan assets at end of year		1,581,000,000	1,729,000,000	1,512,000,000
Funded status at end of year		218,000,000	200,000,000
Noncurrent pension and other postretirement benefit assets		276,000,000	261,000,000
Other current liabilities		(2,000,000)
Noncurrent pension and other postretirement benefit liabilities		(56,000,000)	(61,000,000)
Net amount recognized		218,000,000	$ 200,000,000
Significant assumptions used to determine benefit obligations
Discount rate			3.76%
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year		290,000,000	$ 320,000,000
Service cost		4,000,000	4,000,000	5,000,000
Interest cost		11,000,000	12,000,000	14,000,000
Benefits paid		(18,000,000)	(19,000,000)
Actuarial (gains) losses during the year		(27,000,000)	34,000,000
Plan amendments	[1]	(4,000,000)	(61,000,000)
Benefit obligation at end of year		256,000,000	290,000,000	320,000,000
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year		333,000,000	299,000,000
Actual return (loss) on plan assets		(16,000,000)	41,000,000
Employer contributions		12,000,000	12,000,000
Benefits paid		(18,000,000)	(19,000,000)
Fair value of plan assets at end of year		311,000,000	333,000,000	$ 299,000,000
Funded status at end of year		55,000,000	43,000,000
Noncurrent pension and other postretirement benefit assets		63,000,000	57,000,000
Noncurrent pension and other postretirement benefit liabilities	[3]	(8,000,000)	(14,000,000)
Net amount recognized		$ 55,000,000	$ 43,000,000
Significant assumptions used to determine benefit obligations
Discount rate		4.37%	3.76%
Other Postretirement Benefits | Minimum
Significant assumptions used to determine benefit obligations
Discount rate		4.37%
Weighted average rate of increase for compensation		4.30%	3.95%
Other Postretirement Benefits | Maximum
Significant assumptions used to determine benefit obligations
Discount rate		4.38%
Weighted average rate of increase for compensation		4.55%	4.11%
[1]	2017 amounts relate primarily to a plan amendment that changed post-65 retiree medical coverage for certain current and future Local 69 retirees effective July 1, 2017.
[2]	2017 amount relates primarily to settlement and curtailment as a result of the voluntary and involuntary separation programs at Dominion Energy Questar.
[3]	Reflected in other deferred credits and other liabilities in Dominion Energy Gas' Consolidated Balance Sheets.

Employee Benefit Plans (Benefit

Employee Benefit Plans (Benefit Obligation in Excess of Plan Assets) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	$ 7,705	$ 8,209
Fair value of plan assets	5,398	6,103
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	164	191
Fair value of plan assets	136	156
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	134	157
Fair value of plan assets	$ 126	$ 143

Employee Benefit Plans (Accumul

Employee Benefit Plans (Accumulated Benefit Obligation in Excess of Plan Assets) (Detail) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
General Discussion Of Pension And Other Postretirement Benefits [Abstract]
Accumulated benefit obligation	$ 7,056	$ 7,392
Fair value of plan assets	$ 5,398	$ 6,103

Employee Benefit Plans (Benef_2

Employee Benefit Plans (Benefit Payments Expected Future Service) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
2,019	$ 407
2,020	405
2,021	426
2,022	442
2,023	465
2024-2028	2,548
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2,019	37
2,020	39
2,021	40
2,022	42
2,023	43
2024-2028	223
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
2,019	98
2,020	99
2,021	99
2,022	99
2,023	98
2024-2028	461
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
2,019	19
2,020	19
2,021	19
2,022	19
2,023	19
2024-2028	$ 90

Employee Benefit Plans (Fair va

Employee Benefit Plans (Fair values of pension and post retirement plan assets by asset category) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Total investments		$ 1,279	$ 1,378
Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total investments	[1]	1,775	1,828
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		7,197	8,062	$ 7,016
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,656	1,803	1,542
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,581	1,729	1,512
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		311	333	$ 299
Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4,424	4,878
Total recorded at NAV	[2]	2,762	3,169
Total investments	[3]	7,186	8,047
Collective Bargaining Agreement | Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,017	1,090
Total recorded at NAV	[2]	636	709
Total investments	[4]	1,653	1,799
Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		18	18
Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	4
Collective Bargaining Agreement | Pension Benefits | US Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,645	1,902
Collective Bargaining Agreement | Pension Benefits | US Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		378	425
Collective Bargaining Agreement | Pension Benefits | Foreign Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,061	1,151
Collective Bargaining Agreement | Pension Benefits | Foreign Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		244	257
Collective Bargaining Agreement | Pension Benefits | Insurance contracts
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		318	352
Collective Bargaining Agreement | Pension Benefits | Insurance contracts | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		73	79
Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		752	770
Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		173	172
Collective Bargaining Agreement | Pension Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		630	685
Collective Bargaining Agreement | Pension Benefits | Government securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		145	153
Collective Bargaining Agreement | Pension Benefits | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	1,849	2,272
Collective Bargaining Agreement | Pension Benefits | Common/collective trust funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	425	509
Collective Bargaining Agreement | Pension Benefits | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	108	111
Collective Bargaining Agreement | Pension Benefits | Real Estate Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	25	25
Collective Bargaining Agreement | Pension Benefits | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	633	606
Collective Bargaining Agreement | Pension Benefits | Private Equity Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	146	135
Collective Bargaining Agreement | Pension Benefits | Fixed Income Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	155	161
Collective Bargaining Agreement | Pension Benefits | Fixed Income Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	36	36
Collective Bargaining Agreement | Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	17	19
Collective Bargaining Agreement | Pension Benefits | Hedge Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	4	4
Collective Bargaining Agreement | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		829	944
Total recorded at NAV	[2]	751	783
Total investments	[5]	1,580	1,727
Collective Bargaining Agreement | Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		143	163
Total recorded at NAV	[2]	168	170
Total investments		311	333
Collective Bargaining Agreement | Other Postretirement Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	3
Collective Bargaining Agreement | Other Postretirement Benefits | US Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		554	636
Collective Bargaining Agreement | Other Postretirement Benefits | US Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		113	130
Collective Bargaining Agreement | Other Postretirement Benefits | Foreign Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		170	196
Collective Bargaining Agreement | Other Postretirement Benefits | Foreign Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		30	33
Collective Bargaining Agreement | Other Postretirement Benefits | Insurance contracts
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		19	21
Collective Bargaining Agreement | Other Postretirement Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		45	46
Collective Bargaining Agreement | Other Postretirement Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		39	42
Collective Bargaining Agreement | Other Postretirement Benefits | Common/collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	650	689
Collective Bargaining Agreement | Other Postretirement Benefits | Common/collective trust funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	148	154
Collective Bargaining Agreement | Other Postretirement Benefits | Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	10	9
Collective Bargaining Agreement | Other Postretirement Benefits | Real Estate Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	2	1
Collective Bargaining Agreement | Other Postretirement Benefits | Private Equity Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	80	73
Collective Bargaining Agreement | Other Postretirement Benefits | Private Equity Funds | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	18	15
Collective Bargaining Agreement | Other Postretirement Benefits | Fixed Income Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	10	11
Collective Bargaining Agreement | Other Postretirement Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total recorded at NAV	[2]	1	1
Level 1 | Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2,771	3,121
Level 1 | Collective Bargaining Agreement | Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		637	697
Level 1 | Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		17	18
Level 1 | Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	4
Level 1 | Collective Bargaining Agreement | Pension Benefits | US Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,645	1,902
Level 1 | Collective Bargaining Agreement | Pension Benefits | US Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		378	425
Level 1 | Collective Bargaining Agreement | Pension Benefits | Foreign Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,061	1,151
Level 1 | Collective Bargaining Agreement | Pension Benefits | Foreign Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		244	257
Level 1 | Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		23	41
Level 1 | Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		5	9
Level 1 | Collective Bargaining Agreement | Pension Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		25	9
Level 1 | Collective Bargaining Agreement | Pension Benefits | Government securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		6	2
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		728	836
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		143	163
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	1
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | US Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		554	636
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | US Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		113	130
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Foreign Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		170	196
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Foreign Equity Securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		30	33
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	2
Level 1 | Collective Bargaining Agreement | Other Postretirement Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	1
Level 2 | Collective Bargaining Agreement | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,653	1,757
Level 2 | Collective Bargaining Agreement | Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		380	393
Level 2 | Collective Bargaining Agreement | Pension Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1
Level 2 | Collective Bargaining Agreement | Pension Benefits | Insurance contracts
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		318	352
Level 2 | Collective Bargaining Agreement | Pension Benefits | Insurance contracts | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		73	79
Level 2 | Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		729	729
Level 2 | Collective Bargaining Agreement | Pension Benefits | Corporate debt instruments | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		168	163
Level 2 | Collective Bargaining Agreement | Pension Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		605	676
Level 2 | Collective Bargaining Agreement | Pension Benefits | Government securities | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		139	151
Level 2 | Collective Bargaining Agreement | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		101	108
Level 2 | Collective Bargaining Agreement | Other Postretirement Benefits | Cash equivalents and other
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	2
Level 2 | Collective Bargaining Agreement | Other Postretirement Benefits | Insurance contracts
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		19	21
Level 2 | Collective Bargaining Agreement | Other Postretirement Benefits | Corporate debt instruments
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		44	44
Level 2 | Collective Bargaining Agreement | Other Postretirement Benefits | Government securities
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		$ 37	$ 41
[1]	See Note 24 for amounts attributable to related parties.
[2]	These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.
[3]	Excludes net assets related to pending sales of securities of $12 million, net accrued income of $21 million, and includes net assets related to pending purchases of securities of $22 million at December 31, 2018. Excludes net assets related to pending sales of securities of $11 million, net accrued income of $19 million, and includes net assets related to pending purchases of securities of $15 million at December 31, 2017.
[4]	Excludes net assets related to pending sales of securities of $3 million, net accrued income of $5 million, and includes net assets related to pending purchases of securities of $5 million at December 31, 2018. Excludes net assets related to pending sales of securities of $3 million, net accrued income of $4 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2017.
[5]	Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2018. Excludes net assets related to pending sales of securities of $1 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $1 million at December 31, 2017.

Employee Benefit Plans (Fair _2

Employee Benefit Plans (Fair values of pension and post retirement plan assets by asset category) (Parenthetical) (Detail) - Collective Bargaining Agreement - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pending sales of securities	$ 12	$ 11
Net accrued income	21	19
Pending purchases of securities	22	15
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Pending sales of securities	1	1
Net accrued income	2	2
Pending purchases of securities	2	1
Dominion Energy Gas Holdings, LLC | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pending sales of securities	3	3
Net accrued income	5	4
Pending purchases of securities	$ 5	$ 3

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) (Detail) - USD ($) $ in Millions		Sep. 30, 2017	Jun. 30, 2017	Jan. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Expected return on plan assets					$ (806)	$ (767)
Dominion Energy Gas Holdings, LLC
Expected return on plan assets					(178)	(165)
Pension Benefits
Service cost					157	138	$ 118
Interest cost					337	345	317
Expected return on plan assets					(663)	(639)	(573)
Amortization of prior service (credit) cost					1	1	1
Amortization of net actuarial loss					193	162	111
Settlements and curtailments							1
Net periodic benefit (credit) cost					25	7	(25)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss					490	142	931
Prior service (credit) cost						5
Settlements and curtailments						1	(1)
Amortization of net actuarial loss					(193)	(162)	(111)
Amortization of prior service credit (cost)					(1)	(1)	(1)
Total recognized in other comprehensive income and regulatory assets and liabilities					$ 296	$ (15)	$ 818
Significant assumptions used to determine periodic cost:
Discount rate		4.05%	4.05%	4.51%			4.46%
Expected long-term rate of return on plan assets					8.75%	8.75%	8.75%
Weighted average rate of increase for compensation					4.09%	4.09%	4.22%
Pension Benefits | Dominion Energy Gas Holdings, LLC
Service cost					$ 18	$ 15	$ 13
Interest cost					29	30	30
Expected return on plan assets					(150)	(141)	(134)
Amortization of net actuarial loss					19	16	13
Net periodic benefit (credit) cost					(84)	(80)	(78)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss					207	(75)	91
Amortization of net actuarial loss					(19)	(16)	(13)
Total recognized in other comprehensive income and regulatory assets and liabilities					$ 188	$ (91)	$ 78
Significant assumptions used to determine periodic cost:
Discount rate					3.81%	4.50%	4.99%
Expected long-term rate of return on plan assets					8.75%	8.75%	8.75%
Weighted average rate of increase for compensation					4.11%	4.11%	3.93%
Pension Benefits | Minimum
Significant assumptions used to determine periodic cost:
Discount rate					3.80%	3.31%	2.87%
Pension Benefits | Maximum
Significant assumptions used to determine periodic cost:
Discount rate					3.81%	4.50%	4.99%
Other Postretirement Benefits
Service cost					$ 27	$ 26	$ 31
Interest cost					56	60	65
Expected return on plan assets					(143)	(128)	(118)
Amortization of prior service (credit) cost					(52)	(51)	(35)
Amortization of net actuarial loss					11	13	8
Net periodic benefit (credit) cost					(101)	(80)	(49)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss					78	12	178
Prior service (credit) cost					(4)	(73)	(216)
Settlements and curtailments						2
Amortization of net actuarial loss					(11)	(13)	(8)
Amortization of prior service credit (cost)					52	51	35
Total recognized in other comprehensive income and regulatory assets and liabilities					$ 115	$ (21)	$ (11)
Significant assumptions used to determine periodic cost:
Discount rate					3.76%
Expected long-term rate of return on plan assets					8.50%	8.50%	8.50%
Weighted average rate of increase for compensation						3.29%	4.22%
Healthcare cost trend rate	[1]				7.00%	7.00%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	[1]				5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	[1],[2]				2,022	2,021	2,020
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Service cost					$ 4	$ 4	$ 5
Interest cost					11	12	14
Expected return on plan assets					(28)	(24)	(23)
Amortization of prior service (credit) cost					(4)	(3)	1
Amortization of net actuarial loss					3	2	1
Net periodic benefit (credit) cost					(14)	(9)	(2)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss					16	18	28
Prior service (credit) cost					(4)	(61)
Amortization of net actuarial loss					(3)	(2)	(1)
Amortization of prior service credit (cost)					4	3	(1)
Total recognized in other comprehensive income and regulatory assets and liabilities					$ 13	$ (42)	$ 26
Significant assumptions used to determine periodic cost:
Discount rate					3.81%	4.47%	4.93%
Expected long-term rate of return on plan assets					8.50%	8.50%	8.50%
Weighted average rate of increase for compensation					4.55%	4.11%	3.93%
Healthcare cost trend rate	[1]				7.00%	7.00%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	[1]				5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	[1]				2,022	2,021	2,020
Other Postretirement Benefits | Minimum
Significant assumptions used to determine periodic cost:
Discount rate						3.92%	3.56%
Weighted average rate of increase for compensation					3.95%
Other Postretirement Benefits | Maximum
Significant assumptions used to determine periodic cost:
Discount rate						4.47%	4.94%
Weighted average rate of increase for compensation					4.11%
[1]	Assumptions used to determine net periodic cost for the following year.
[2]	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) (Detail) - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		$ 1,700	$ 659
Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		169	98
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		3,477	3,181
Prior service (credit) cost		7	8
Total	[1]	3,484	3,189
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		555	367
Total	[2]	555	367
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		350	283
Prior service (credit) cost		(393)	(440)
Total	[1]	(43)	(157)
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		89	76
Prior service (credit) cost		(52)	(52)
Total	[2]	$ 37	$ 24
[1]	As of December 31, 2018, of the $3.5 billion and $(43) million related to pension benefits and other postretirement benefits, $2.0 billion and $(41) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2017, of the $3.2 billion and $(157) million related to pension benefits and other postretirement benefits, $1.9 billion and $(87) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
[2]	As of December 31, 2018, of the $555 million related to pension benefits, $200 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $37 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2017, of the $367 million related to pension benefits, $134 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $24 million related to other postretirement benefits is included entirely in regulatory assets and liabilities.

Employee Benefit Plans (AOCI _2

Employee Benefit Plans (AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost) (Parenthetical) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[1]	$ 3,484	$ 3,189
Amount included in AOCI		2,000	1,900
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[1]	(43)	(157)
Amount included in AOCI		(41)	(87)
Dominion Energy Gas Holdings, LLC | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[2]	555	367
Amount included in AOCI		200	134
Dominion Energy Gas Holdings, LLC | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[2]	$ 37	$ 24
[1]	As of December 31, 2018, of the $3.5 billion and $(43) million related to pension benefits and other postretirement benefits, $2.0 billion and $(41) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2017, of the $3.2 billion and $(157) million related to pension benefits and other postretirement benefits, $1.9 billion and $(87) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
[2]	As of December 31, 2018, of the $555 million related to pension benefits, $200 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $37 million related to other postretirement benefits is included entirely in regulatory assets and liabilities. As of December 31, 2017, of the $367 million related to pension benefits, $134 million is included in AOCI, with the remainder included in regulatory assets and liabilities; the $24 million related to other postretirement benefits is included entirely in regulatory assets and liabilities.

Employee Benefit Plans (Compone

Employee Benefit Plans (Components of AOCI and Regulatory Assets and Liabilities) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	$ 155
Prior service (credit) cost	1
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	19
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	18
Prior service (credit) cost	(52)
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	4
Prior service (credit) cost	$ (4)

Employee Benefit Plans (Effect

Employee Benefit Plans (Effect of One Percentage Point Change on Benefit Plans) (Detail) - Other Postretirement Benefits $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Defined Benefit Plan Disclosure [Line Items]
Effect of one percentage point increase on total of service and interest cost components	$ 20
Effect of one percentage point increase on other postretirement benefit obligation	130
Effect of one percentage point decrease on total of service and interest cost components	(16)
Effect of one percentage point decrease on other postretirement benefit obligation	(110)
Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Effect of one percentage point increase on total of service and interest cost components	4
Effect of one percentage point increase on other postretirement benefit obligation	25
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	$ (22)

Commitments and Contingencies_2

Commitments and Contingencies (Narrative) (Detail) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Dec. 31, 2018USD ($)siteParties

Aug. 31, 2018USD ($)

Jun. 30, 2018USD ($)

Sep. 30, 2017

Jul. 31, 2017

Jun. 30, 2017

May 31, 2017Counts

Apr. 30, 2017PetitionStation

Mar. 31, 2017Counts

Aug. 31, 2016T

Jul. 31, 2016Parties

Apr. 30, 2015Facilities

Dec. 31, 2018USD ($)site

Jun. 30, 2018USD ($)

Dec. 31, 2018USD ($)siteFacilitiesFacilityIndicatorsgal

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Oct. 31, 2017USD ($)

Oct. 31, 2015PartsPerBillion

Jul. 31, 2015Counts

Loss Contingencies [Line Items]

Environmental Remediation Expense

$ 81

$ 197

ARO incurred

20

$ 37

Regulatory liability

$ 7,196

$ 7,196

7,196

7,109

Virginia Electric and Power Company

Loss Contingencies [Line Items]

Environmental Remediation Expense

81

197

ARO incurred

14

11

Regulatory liability

4,946

4,946

4,946

4,887

Virginia Electric and Power Company | Future Ash Pond and Landfill Closure Costs

Loss Contingencies [Line Items]

ARO incurred

$ 131

238

$ 386

Virginia Electric and Power Company | Increase In Property Plant And Equipment

Loss Contingencies [Line Items]

ARO incurred

46

17

Virginia Electric and Power Company | Increase in Regulatory Assets

Loss Contingencies [Line Items]

ARO incurred

4

24

Virginia Electric and Power Company | Other operations and maintenance

Loss Contingencies [Line Items]

ARO incurred

81

$ 197

ARO incurred, after tax

60

Dominion Energy Gas Holdings, LLC

Loss Contingencies [Line Items]

ARO incurred

4

2

Regulatory liability

1,306

1,306

1,306

$ 1,265

FERC-regulated | Virginia Electric and Power Company | Pending Litigation [Member]

Loss Contingencies [Line Items]

Regulatory liability

$ 14

14

$ 14

CWA | Virginia Electric and Power Company | Minimum | Chesapeake power station [Member] | Judicial Ruling

Loss Contingencies [Line Items]

Additional specific sediment, water and aquatic life monitoring period

2 years

CWA | EPA | Final Rule to Revise Effluent Limitations Guidelines for Steam Electric Power Generating Category

Loss Contingencies [Line Items]

Compliance date

2023-12

CWA | EPA | 2015 Effluent Limitations Guidelines Rule for Steam Electric Power Generating Category

Loss Contingencies [Line Items]

Compliance date

2020-11

Unfavorable Regulatory Action | EPA

Loss Contingencies [Line Items]

Significant emission rate per rear CO2 equivalent | T

75,000

Electric generating station facilities heightened entrainment analysis per day | gal

125,000,000

Unfavorable Regulatory Action | MATS | EPA | Virginia Electric and Power Company

Loss Contingencies [Line Items]

Number of effective days to operate power station units

90 days

Unfavorable Regulatory Action | Ozone Standards | EPA

Loss Contingencies [Line Items]

Standard emission level prior to revision | PartsPerBillion

75

Revised emission standard level | PartsPerBillion

70

Unfavorable Regulatory Action | Ozone Standards | EPA | Minimum

Loss Contingencies [Line Items]

Estimated compliance costs

$ 25

Unfavorable Regulatory Action | Ozone Standards | EPA | Maximum

Loss Contingencies [Line Items]

Estimated compliance costs

$ 35

Unfavorable Regulatory Action | Regulations To Reduce Nitrogen Oxideand Volatile Organic Compounds Emissions [Member] | Pennsylvania Department Of Environmental Protection [Member] | Dominion Gas Holdings, LLC

Loss Contingencies [Line Items]

Estimated compliance costs

$ 35

Unfavorable Regulatory Action | CWA

Loss Contingencies [Line Items]

Number of facilities that may be subject to final regulations | Facility

13

Unfavorable Regulatory Action | CWA | Virginia Electric and Power Company

Loss Contingencies [Line Items]

Number of facilities that may be subject to final regulations | Facility

11

Number of mandatory facility-specific factors | Indicators

5

Number of optional facility-specific factors | Indicators

6

Number of facilities subject to regulations | Facilities

9

Unfavorable Regulatory Action | CWA | Virginia Electric and Power Company | Minimum

Loss Contingencies [Line Items]

Electric generating stations with water withdrawals per day | gal

2,000,000

Unfavorable Regulatory Action | CWA | EPA | Final Rule to Revise Effluent Limitations Guidelines for Steam Electric Power Generating Category

Loss Contingencies [Line Items]

Number of separate petitions for reconsideration granted | Petition

2

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA

Loss Contingencies [Line Items]

Number of former manufactured gas plant sites | site

22

22

22

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | Former Gas Plant Site with Post Closure Groundwater Monitoring Program

Loss Contingencies [Line Items]

Number of former sites | site

1

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | Virginia Electric and Power Company

Loss Contingencies [Line Items]

Number of former manufactured gas plant sites | site

3

3

3

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | Virginia Electric and Power Company | Former Gas Plant Site with Post Closure Groundwater Monitoring Program

Loss Contingencies [Line Items]

Estimated compliance costs

$ 18

$ 18

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | Virginia Electric and Power Company | Former Gas Plant Site with Post Closure Groundwater Monitoring Program | Other operations and maintenance

Loss Contingencies [Line Items]

Environmental Remediation Expense

16

Environmental Remediation Expense, net of tax

$ 12

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | SCANA

Loss Contingencies [Line Items]

Estimated compliance costs

$ 10

$ 10

$ 10

Number of sites under investigation, remediation and monitoring | site

4

Number of sites with an updated remediation work plan | site

1

Updated remediation work plan, cost increase

$ 8

Unfavorable Regulatory Action | Coal Tar and Other Potentially Harmful Materials | EPA | Dominion Energy Gas Holdings, LLC

Loss Contingencies [Line Items]

Number of former manufactured gas plant sites | site

12

12

12

Unfavorable Regulatory Action | CCR | EPA | Facilities Subject to Coal Combustion Residual Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs

Loss Contingencies [Line Items]

Number of facilities with CCR | Facilities

11

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

Loss Contingencies [Line Items]

Number of facilities with CCR | Facilities

8

Number of stations | Station

4

Breach of Contract Lawsuit | DETI | Pending Litigation [Member]

Loss Contingencies [Line Items]

Total number of counts in complaint | Counts

8

Breach of Contract Lawsuit | DETI | Judicial Ruling

Loss Contingencies [Line Items]

Number of counts dismissed | Counts

3

Breach of Contract Lawsuit | DETI | Settled Litigation

Loss Contingencies [Line Items]

Number of claims withdrew | Counts

1

payment of litigation Settlement agreement

$ 14

Liquefaction Project | FERC-regulated | Cove Point | Pending Litigation [Member]

Loss Contingencies [Line Items]

Number of parties | Parties

2

Liquefaction Project | FERC-regulated | Cove Point | Judicial Ruling

Loss Contingencies [Line Items]

Number of parties | Parties

1

Commitments and Contingencies_3

Commitments and Contingencies (Nuclear Operations) (Narrative) (Detail) - USD ($)	3 Months Ended			12 Months Ended
	Dec. 31, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Loss Contingencies [Line Items]
NRC minimum requirement for nuclear power plant licensees	$ 1,060,000,000			$ 1,060,000,000
Maximum assessment for premiums on insurance policy				83,000,000
Maximum assessment for insurance policy				21,000,000
Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables	49,000,000			49,000,000	$ 46,000,000
Maximum
Loss Contingencies [Line Items]
Amount that could be assessed for each licensed reactor	138,000,000			138,000,000
Amount that could be assessed for each licensed reactor per reactor	21,000,000			$ 21,000,000
Nuclear Obligations
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount	14,100,000,000	$ 13,100,000,000	$ 13,400,000,000
Inflationary provision adjustment period				5 years
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Maximum assessment for premiums on insurance policy				$ 51,000,000
Maximum assessment for insurance policy				10,000,000
Virginia Electric and Power Company | Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables	30,000,000			30,000,000	30,000,000
Dominion Energy and Virginia Electric and Power
Loss Contingencies [Line Items]
Amount of coverage purchased from commercial insurance pools	450,000,000			450,000,000
Surry and North Anna
Loss Contingencies [Line Items]
Settlement amount				16,000,000	22,000,000	$ 30,000,000
Millstone
Loss Contingencies [Line Items]
Settlement amount				13,000,000	$ 14,000,000	$ 22,000,000
Millstone Unit 1
Loss Contingencies [Line Items]
Minimum financial assurance	2,700,000,000			2,700,000,000
Kewaunee | Nuclear Obligations
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount				100,000,000
Kewaunee | Virginia Electric and Power Company
Loss Contingencies [Line Items]
Minimum financial assurance	$ 1,800,000,000			$ 1,800,000,000

Commitments and Contingencies_4

Commitments and Contingencies (Nuclear Insurance) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Millstone
Guarantor Obligations [Line Items]
Property insurance coverage	$ 1,700
Kewaunee
Guarantor Obligations [Line Items]
Property insurance coverage	50
Surry | Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Property insurance coverage	1,700	[1]
North Anna | Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Property insurance coverage	$ 1,700	[1]
[1]	Surry and North Anna share a blanket property limit of $200 million.

Commitments and Contingencies_5

Commitments and Contingencies (Nuclear Insurance) (Parenthetical) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Surry and North Anna
Guarantor Obligations [Line Items]
Coverage amount	$ 200

Commitment and Contingencies (S

Commitment and Contingencies (Schedule of Long Term Purchase Commitments) (Detail) - Virginia Electric and Power Company - Purchased electric capacity $ in Millions	Dec. 31, 2018USD ($)	[1]
Long-term Purchase Commitment [Line Items]
2,019	$ 60
2,020	52
2,021	46
Thereafter	0
Total	$ 158
[1]	Commitments represent estimated amounts payable for capacity under power purchase contracts with independent power producers, which end 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, 2018, the present value of Virginia Power's total commitment for capacity payments is $142 million. Capacity payments totaled $50 million, $114 million and $248 million, and energy payments totaled $42 million, $72 million and $126 million for the years ended 2018, 2017 and 2016, respectively.

Commitment and Contingencies _2

Commitment and Contingencies (Schedule of Long Term Purchase Commitments) (Parenthetical) (Detail) - Virginia Electric and Power Company - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Long-term Purchase Commitment [Line Items]
Present value of total commitment for capacity payments	$ 142
Purchased electric capacity
Long-term Purchase Commitment [Line Items]
Payments	50	$ 114	$ 248
Energy payments
Long-term Purchase Commitment [Line Items]
Payments	$ 42	$ 72	$ 126

Commitments and Contingencies_6

Commitments and Contingencies (Lease Commitments) (Detail) $ in Millions	Dec. 31, 2018USD ($)
Loss Contingencies [Line Items]
2,019	$ 64
2,020	61
2,021	55
2,022	47
2,023	38
Thereafter	384
Total	649
Virginia Electric and Power Company
Loss Contingencies [Line Items]
2,019	34
2,020	32
2,021	28
2,022	22
2,023	16
Thereafter	106
Total	238
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
2,019	12
2,020	11
2,021	9
2,022	7
2,023	4
Thereafter	3
Total	$ 46

Commitments and Contingencies_7

Commitments and Contingencies (Lease Commitments) (Narrative) (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Loss Contingencies [Line Items]
Rental expense		$ 109	$ 113	$ 104
Corporate office | Agreement with Lessor to Construct and Lease Corporate Office Property
Loss Contingencies [Line Items]
Requested cash draws from lessor to fund project costs		281
Required percentage payment of funded amount under certain events of default	89.90%
Required percentage payment for specific full recourse events	100.00%
Lease term	5 years
Extension term of lease	5 years
Required percentage payment to lessor for difference between project costs and sales proceeds	87.00%
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Rental expense		63	57	52
Dominion Gas Holdings, LLC
Loss Contingencies [Line Items]
Rental expense		$ 22	$ 34	$ 37
Lessor | Corporate office | Agreement with Lessor to Construct and Lease Corporate Office Property
Loss Contingencies [Line Items]
Amount of financing commitments to fund estimated project costs	$ 365

Commitments and Contingencies_8

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Detail) - USD ($)		1 Months Ended	2 Months Ended	12 Months Ended
		Oct. 31, 2017	Feb. 28, 2019	Dec. 31, 2018		Dec. 31, 2017
Guarantor Obligations [Line Items]
Facility Limit				$ 6,000,000,000	[1]	$ 5,500,000,000
Maximum Exposure	[2]			5,344,000,000
Cove Point
Guarantor Obligations [Line Items]
Maximum Exposure	[3]			1,900,000,000
Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Facility Limit				6,000,000,000	[4]	5,500,000,000
Dominion Energy Gas Holdings, LLC
Guarantor Obligations [Line Items]
Facility Limit				1,500,000,000	[5]	1,500,000,000
Nuclear Obligations
Guarantor Obligations [Line Items]
Maximum Exposure	[6]			179,000,000
Commodity Transactions
Guarantor Obligations [Line Items]
Maximum Exposure	[7]			2,186,000,000
Financial Guarantee [Member] | Revolving Credit Facility | Atlantic Coast Pipeline
Guarantor Obligations [Line Items]
Facility Limit		$ 3,400,000,000
Revolving credit facility stated maturity date		Oct. 31, 2021
Maximum potential loss exposure, limited guarantee percentage		48.00%
Guarantee liability				21,000,000		$ 28,000,000
Guarantee recorded amount				1,400,000,000
Financial Guarantee [Member] | Equity Method Investee [Member]
Guarantor Obligations [Line Items]
Maximum Exposure				48,000,000
Solar
Guarantor Obligations [Line Items]
Maximum Exposure	[8]			659,000,000
Other
Guarantor Obligations [Line Items]
Maximum Exposure	[9]			420,000,000
Surety Bond [Member]
Guarantor Obligations [Line Items]
Maximum Exposure				171,000,000
Surety Bond [Member] | Virginia Electric and Power Company
Guarantor Obligations [Line Items]
Maximum Exposure				72,000,000
Surety Bond [Member] | Dominion Energy Gas Holdings, LLC
Guarantor Obligations [Line Items]
Maximum Exposure				26,000,000
Financial Standby Letter of Credit [Member]
Guarantor Obligations [Line Items]
Maximum Exposure				88,000,000
Subsequent Event | Financial Guarantee [Member] | Revolving Credit Facility | Atlantic Coast Pipeline
Guarantor Obligations [Line Items]
Additional borrowing			$ 113,000,000
Minimum | Financial Guarantee [Member] | Affiliated Entity
Guarantor Obligations [Line Items]
Maximum annual future contributions				4,000,000
Maximum | Financial Guarantee [Member] | Affiliated Entity
Guarantor Obligations [Line Items]
Maximum annual future contributions				$ 4,000,000
[1]	This credit facility matures in March 2023 and can be used by the Companies 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]	Excludes Dominion Energy's guarantee for the construction of the new corporate office property discussed further within Lease Commitments above.
[3]	Guarantees related to Cove Point, in support of terminal services, transportation and construction. Cove Point has two guarantees that have no maximum limit and, therefore, are not included in this amount.
[4]	The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Virginia Power was $1.5 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 Energy. This credit facility matures in March 2023 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.
[5]	A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At December 31, 2018, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy 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 Energy. This credit facility matures in March 2023 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.
[6]	Guarantees related to certain DGI subsidiaries' regarding all aspects of running a nuclear facility.
[7]	Guarantees related to commodity commitments of certain subsidiaries. These guarantees were provided to counterparties in order to facilitate physical and financial transaction related commodities and services.
[8]	Includes guarantees to facilitate the development of solar projects. Also includes guarantees entered into by DGI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.
[9]	Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Due to the uncertainty of worker's compensation claims, the parental guarantee has no stated limit. Also included are guarantees related to certain DGI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of December 31, 2018, Dominion Energy's maximum remaining cumulative exposure under these equity funding agreements is $4 million through 2019 and its maximum annual future contribution is approximately $4 million.

Credit Risk (Narrative) (Detail

Credit Risk (Narrative) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)CounterpartyCustomer	Dec. 31, 2017USD ($)
Concentration Risk And Guarantor Obligations [Line Items]
Gross credit exposure	$ 145
Additional collateral to be posted if the credit related contingent features were triggered	1	$ 62
Aggregate fair value of all derivative instruments with credit contingent provisions that are in a liability position	1	$ 65
Virginia Electric and Power Company
Concentration Risk And Guarantor Obligations [Line Items]
Gross credit exposure	10
Dominion Energy Gas Holdings, LLC
Concentration Risk And Guarantor Obligations [Line Items]
Gross credit exposure	$ 8
Credit Concentration Risk
Concentration Risk And Guarantor Obligations [Line Items]
Number of counterparties | Counterparty	0
Amount of exposure for single counterparty	$ 47
Credit Concentration Risk | Virginia Electric and Power Company
Concentration Risk And Guarantor Obligations [Line Items]
Amount of exposure for single counterparty	$ 9
Credit Concentration Risk | Dominion Energy Gas Holdings, LLC
Concentration Risk And Guarantor Obligations [Line Items]
Number of counterparties | Counterparty	0
Amount of exposure for single counterparty	$ 5
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	69.00%
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty | Dominion Energy Gas Holdings, LLC
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	93.00%
Customer Concentration Risk | Sales Revenue, Net | Dominion Energy Gas Holdings, LLC
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	96.00%
Number of customers | Customer	307
Customer Concentration Risk | Sales Revenue, Net | Dominion Energy Gas Holdings, LLC | Ten Largest Customers
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	38.00%
Number of customers | Customer	10
Customer Concentration Risk | Sales Revenue, Net | Dominion Energy Gas Holdings, LLC | Thirty Largest Customers
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	71.00%
Number of customers | Customer	30
Customer Concentration Risk | Sales Revenue, Net | East Ohio
Concentration Risk And Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	99.00%

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Detail) - USD ($) shares in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017		Dec. 31, 2016
Related Party Transaction [Line Items]
Derivative Asset	$ 294,000,000	$ 307,000,000
Derivative Liabilities	279,000,000	284,000,000
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Derivative Asset	29,000,000	32,000,000	[1]
Derivative Liabilities	19,000,000	8,000,000
Short term demand note	218,000,000	18,000,000
Dominion Energy Gas Holdings, LLC | Revolving Credit Facility | IRCA
Related Party Transaction [Line Items]
Short term demand note	$ 218,000,000	$ 18,000,000
Weighted- average interest rate percentage	2.78%	1.60%
Dominion Energy Gas Holdings, LLC | Pension Benefits | Amounts Associated with the Dominion Pension Plan
Related Party Transaction [Line Items]
Amounts due from Dominion, noncurrent	$ 772,000,000	$ 734,000,000
Dominion Energy Gas Holdings, LLC | Medical Coverage for Local retirees | Amounts Associated with the Dominion Retiree Health and Welfare Plan
Related Party Transaction [Line Items]
Amounts due from Dominion, noncurrent	14,000,000	7,000,000
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Derivative Asset	93,000,000	166,000,000
Derivative Liabilities	103,000,000	66,000,000
Short term demand note	224,000,000	33,000,000
Outstanding borrowings, net of repayments, under money pool for non-regulated subsidiaries	$ 0	$ 0
Issuance of common stock (in shares)	0	0		0
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Derivative Asset	$ 26,000,000	$ 11,000,000
Derivative Liabilities	10,000,000	5,000,000
Virginia Electric and Power Company | Principal Owner
Related Party Transaction [Line Items]
Short term demand note	$ 224,000,000	$ 33,000,000
Weighted- average interest rate percentage	2.94%	1.65%
Virginia Electric and Power Company | Pension Benefits | Amounts Associated with the Dominion Pension Plan
Related Party Transaction [Line Items]
Amounts due to Dominion, noncurrent	$ 632,000,000	$ 505,000,000
Virginia Electric and Power Company | Medical Coverage for Local retirees | Amounts Associated with the Dominion Retiree Health and Welfare Plan
Related Party Transaction [Line Items]
Amounts due from Dominion, noncurrent	$ 254,000,000	$ 199,000,000
[1]	Current derivative liabilities are presented in other current liabilities in Virginia Power's Consolidated Balance Sheets.

Related-Party Transactions (Det

Related-Party Transactions (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Commodity purchases from affiliates		$ 930	$ 674	$ 571
Services provided by affiliates	[1]	450	453	454
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Services provided to related parties		24	25	22
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Services provided to related parties	[2]	216	156	128
Commodity purchases from affiliates		58	70	69
Services provided by affiliates	[3]	131	143	141
Other receivables	[4]	13	12
Customer receivables from related parties		1	1
Affiliated notes receivable	[5]	16	20
Dominion Energy Gas Holdings, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Services provided to related parties		6	5	$ 9
Imbalances receivable from affiliates		1	$ 1
Imbalances payable to affiliates	[6]	$ 13
[1]	Includes capitalized expenditures of $145 million, $144 million and $144 million for the year ended December 31, 2018, 2017 and 2016, respectively.
[2]	Amounts primarily attributable to Atlantic Coast Pipeline, a related party VIE.
[3]	Includes capitalized expenditures of $37 million, $45 million and $49 million for the year ended December 31, 2018, 2017 and 2016, respectively.
[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 Energy Gas' Consolidated Balance Sheets.
[6]	Amounts are presented in other current liabilities in Dominion Energy Gas' Consolidated Balance Sheets.

Related-Party Transactions (Par

Related-Party Transactions (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Capital expenditures	$ 4,254	$ 5,504	$ 6,085
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Capital expenditures	2,228	2,496	2,489
Virginia Electric and Power Company | Services provided by affiliates | Affiliated Entity
Related Party Transaction [Line Items]
Capital expenditures	145	144	144
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Capital expenditures	772	778	854
Dominion Energy Gas Holdings, LLC | Services provided by affiliates | Affiliated Entity
Related Party Transaction [Line Items]
Capital expenditures	$ 37	$ 45	$ 49

Operating Segments (Narrative)

Operating Segments (Narrative) (Detail) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
After-tax charge related to the impairment of gathering and processing assets	$ 164
Net loss related to investments in nuclear decommissioning trust funds, after tax				$ (17)	$ 141	$ (325)
Charge for disallowance of FERC-regulated plant, after tax		$ 89
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities				81		197
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act			$ (851)	46	(851)	0
Charges associated with equity method investments in wind-powered generation facilities					158
Charges associated with equity method investments in wind-powered generation facilities, after tax					96
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Net loss related to investments in nuclear decommissioning trust funds, after tax				2	16	6
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities				81		197
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act			(93)	21	(93)	0
Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Net loss related to investments in nuclear decommissioning trust funds, after tax				(45)	25	(24)
Charge for disallowance of FERC-regulated plant, after tax		$ 89
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act			$ (197)	(11)	(197)	0
Operating Segments
Segment Reporting Information [Line Items]
After-tax net (expenses) benefit				88	861	(180)
Benefit associated with sale of certain merchant generation facilities and equity method investments				828
Benefit associated with sale of certain merchant generation facilities and equity method investments, after tax				619
Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act					(93)
Operating Segments | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
After-tax net (expenses) benefit				(244)	(174)	(7)
Charge related to impairment of certain gathering and processing assets				219
After-tax charge related to the impairment of gathering and processing assets				165
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act					185
Charge for disallowance of FERC-regulated plant				124
After-tax charge for disallowance of FERC-regulated plant				88
Operating Segments | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative						59
Organizational design initiative charges, after tax						36
Operating Segments | Organizational Design Initiative | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Organizational design initiative						8
Organizational design initiative charges, after tax						5
Operating Segments | Virginia Legislation [Member]
Segment Reporting Information [Line Items]
One-time rate credit amount				215
One-time rate credit amount after tax				160
Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
After-tax net (expenses) benefit				608	389	(484)
Operating Segments | Corporate and Other | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After-tax net (expenses) benefit				(312)	74	(173)
Operating Segments | Corporate and Other | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
After-tax net (expenses) benefit				(251)	(179)	(3)
Operating Segments | Gas Infrastructure
Segment Reporting Information [Line Items]
Charge related to impairment of certain gathering and processing assets				219
After-tax charge related to the impairment of gathering and processing assets				164
Benefit associated with sale of certain merchant generation facilities and equity method investments, after tax				390
Operating Segments | Gas Infrastructure | FERC-Regulated Plant
Segment Reporting Information [Line Items]
Charge for disallowance of FERC-regulated plant				124
Charge for disallowance of FERC-regulated plant, after tax				88
Operating Segments | Gas Infrastructure | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative charges, after tax						12
Operating Segments | Power Generation
Segment Reporting Information [Line Items]
Net loss related to investments in nuclear decommissioning trust funds				(170)
Net loss related to investments in nuclear decommissioning trust funds, after tax				(134)
Charges associated with equity method investments in wind-powered generation facilities					158
Charges associated with equity method investments in wind-powered generation facilities, after tax					96
Operating Segments | Power Generation | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative charges, after tax						19
Operating Segments | Power Generation | Virginia Legislation [Member]
Segment Reporting Information [Line Items]
Charge associated with one-time rate credits of certain amounts to utility customers, after tax				109
Operating Segments | Power Generation | Virginia Regulation
Segment Reporting Information [Line Items]
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities				81
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities, after tax				60
Operating Segments | Power Generation | Facilities Subject to Coal Combustion Residual Final Rule
Segment Reporting Information [Line Items]
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities						197
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities, after tax						122
Operating Segments | Power Generation | Facilities Subject to Coal Combustion Residual Final Rule | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities						197
Charge associated with asset retirement obligations for ash ponds and landfills at certain utility generation facilities, after tax						121
Operating Segments | Power Delivery
Segment Reporting Information [Line Items]
Charge associated with major storm damage and service restoration				70
Charge associated with major storm damage and service restoration, after tax				52
Benefit associated with sale of certain merchant generation facilities and equity method investments, after tax				229
Operating Segments | Power Delivery | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative charges, after tax						$ 5
Operating Segments | Power Delivery | Virginia Legislation [Member]
Segment Reporting Information [Line Items]
Charge associated with one-time rate credits of certain amounts to utility customers, after tax				$ 51
Operating Segments | Remeasured Subsequent To Initial Recognition [Member]
Segment Reporting Information [Line Items]
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act					(979)
Operating Segments | Remeasured Subsequent To Initial Recognition [Member] | Gas Infrastructure
Segment Reporting Information [Line Items]
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act					(324)
Operating Segments | Remeasured Subsequent To Initial Recognition [Member] | Power Generation
Segment Reporting Information [Line Items]
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act					$ (655)

Operating Segments (Schedule of

Operating Segments (Schedule of Segment Reporting Information, by Segment) (Detail) - USD ($) $ in Millions		3 Months Ended								12 Months Ended
		Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Segment Reporting Information [Line Items]
Operating revenue		$ 3,361	$ 3,451	$ 3,088	$ 3,466	$ 3,210	$ 3,179	$ 2,813	$ 3,384	$ 13,366	[1]	$ 12,586	[1]	$ 11,737	[1]
Depreciation and amortization										2,000		1,905		1,559
Impairment of assets and related charges										403		15		4
Gains on sales of assets										(380)		(147)		(40)
Equity in earnings of equity method investees										197		(18)		111
Interest income										84		82		66
Interest and related charges										1,493		1,205		1,010
Income tax expense (benefit)										580		(30)		655
Net income		641	854	449	503	1,312	665	390	632	2,447		2,999		2,123
Investment in equity method investees		1,278				1,544				1,278		1,544
Capital expenditures										4,405		5,909		6,125
Capital expenditures										4,254		5,504		6,085
Total assets		77,914				76,585				77,914		76,585
Total assets		77,914				76,585				77,914		76,585
Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating revenue		532	423	459	526	501	401	422	490	1,940	[2]	1,814	[2]	1,638	[2]
Depreciation and amortization										244		227		204
Impairment of assets and related charges		219								346		16
Gains on sales of assets										(119)		(70)		(45)
Equity in earnings of equity method investees										24		21		21
Interest income										2		2		1
Interest and related charges	[2]									105		97		94
Income tax expense (benefit)										86		51		215
Net income		(16)	136	15	166	313	117	77	108	301		615		392
Investment in equity method investees		91				95				91		95
Capital expenditures										772		778		854
Total assets		12,351				11,940				12,351		11,940
Total assets		12,351				11,940				12,351		11,940
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue		1,810	2,232	1,829	1,748	1,824	2,154	1,747	1,831	7,619	[3]	7,556	[3]	7,588	[3]
Depreciation and amortization										1,132		1,141		1,025
Interest income										10		19
Interest and related charges	[3]									511		494		461
Income tax expense (benefit)										300		774		727
Net income		239	$ 520	$ 339	$ 184	407	$ 459	$ 318	$ 356	1,282		1,540		1,218
Capital expenditures										2,542		2,729		2,649
Capital expenditures										2,228		2,496		2,489
Total assets		36,880				35,139				36,880		35,139
Total assets		36,880				35,139				36,880		35,139
Gas Infrastructure
Segment Reporting Information [Line Items]
Operating revenue										4,221		2,832		2,069
Gas Infrastructure | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating revenue										1,940		1,814		1,638
Depreciation and amortization										244		227		214
Impairment of assets and related charges										5		15
Gains on sales of assets										(119)		(70)		(45)
Equity in earnings of equity method investees										24		21		21
Interest income										2		2		1
Interest and related charges										104		97		92
Income tax expense (benefit)										188		256		237
Net income										552		436		395
Investment in equity method investees		91				95				91		95
Capital expenditures										772		778		854
Total assets		11,800				11,300				11,800		11,300
Total assets		11,800				11,300				11,800		11,300
Corporate and Other
Segment Reporting Information [Line Items]
Operating revenue										(208)		16		(7)
Corporate and Other | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Depreciation and amortization														(10)
Impairment of assets and related charges										341		1
Interest and related charges										1				2
Income tax expense (benefit)										(102)		(205)		(22)
Net income										(251)		179		(3)
Total assets		600				600				600		600
Total assets		600				600				600		600
Power Delivery
Segment Reporting Information [Line Items]
Operating revenue										2,206		2,206		2,210
Power Generation
Segment Reporting Information [Line Items]
Operating revenue										7,104		6,676		6,747
Adjustments & Eliminations
Segment Reporting Information [Line Items]
Operating revenue										43		856		718
Adjustments & Eliminations | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Interest income										(4)		(3)
Interest and related charges										(4)		(3)		(2)
Total assets		(0.1)				(0.1)				(0.1)		(0.1)
Total assets		(0.1)				(0.1)				(0.1)		(0.1)
Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue										(735)		(1,476)		(1,339)
Intersegment revenue | Gas Infrastructure
Segment Reporting Information [Line Items]
Operating revenue										27		834		697
Intersegment revenue | Corporate and Other
Segment Reporting Information [Line Items]
Operating revenue										674		610		609
Intersegment revenue | Power Delivery
Segment Reporting Information [Line Items]
Operating revenue										23		22		23
Intersegment revenue | Power Generation
Segment Reporting Information [Line Items]
Operating revenue										11		10		10
Eliminations
Segment Reporting Information [Line Items]
Operating revenue										(692)		(620)		(621)
Operating Segments
Segment Reporting Information [Line Items]
Operating revenue										13,366		12,586		11,737
Operating Segments | Gas Infrastructure
Segment Reporting Information [Line Items]
Operating revenue										4,248		3,666		2,766
Depreciation and amortization										615		522		330
Impairment of assets and related charges										8
Gains on sales of assets										(186)		(147)		(44)
Equity in earnings of equity method investees										178		159		105
Interest income										64		45		34
Interest and related charges										268		109		38
Income tax expense (benefit)										330		487		431
Net income										1,214		898		726
Investment in equity method investees		1,159				1,422				1,159		1,422
Capital expenditures										1,415		2,149		2,322
Total assets		31,500				28,000				31,500		28,000
Total assets		31,500				28,000				31,500		28,000
Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Operating revenue										466		626		602
Depreciation and amortization										14		43		30
Impairment of assets and related charges										394		15		4
Gains on sales of assets										(200)
Equity in earnings of equity method investees										1		4		22
Interest income										126		96		36
Interest and related charges										782		644		516
Income tax expense (benefit)										(204)		(1,224)		(363)
Net income										(608)		389		(484)
Investment in equity method investees		37				41				37		41
Capital expenditures										105		52		43
Total assets		11,200				12,000				11,200		12,000
Total assets		11,200				12,000				11,200		12,000
Operating Segments | Corporate and Other | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue										(215)				(19)
Depreciation and amortization										(25)
Interest income										5		3
Income tax expense (benefit)										(78)		(94)		(104)
Net income										(312)		74		(173)
Operating Segments | Power Delivery
Segment Reporting Information [Line Items]
Operating revenue										2,229		2,228		2,233
Depreciation and amortization										625		593		537
Interest income												4
Interest and related charges										265		265		244
Income tax expense (benefit)										160		334		308
Net income										587		531		484
Capital expenditures										1,564		1,433		1,320
Total assets		17,800				16,700				17,800		16,700
Total assets		17,800				16,700				17,800		16,700
Operating Segments | Power Delivery | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue										2,204		2,212		2,217
Depreciation and amortization										624		594		537
Interest income												4
Interest and related charges										265		265		244
Income tax expense (benefit)										158		334		307
Net income										586		527		482
Capital expenditures										1,539		1,439		1,313
Total assets		17.6				16.6				17.6		16.6
Total assets		17.6				16.6				17.6		16.6
Operating Segments | Power Generation
Segment Reporting Information [Line Items]
Operating revenue										7,115		6,686		6,757
Depreciation and amortization										746		747		662
Impairment of assets and related charges										1
Gains on sales of assets										6				4
Equity in earnings of equity method investees										18		(181)		(16)
Interest income										90		92		74
Interest and related charges										374		342		290
Income tax expense (benefit)										294		373		279
Net income										1,254		1,181		1,397
Investment in equity method investees		82				81				82		81
Capital expenditures										1,321		2,275		2,440
Total assets		28,200				29,000				28,200		29,000
Total assets		28,200				29,000				28,200		29,000
Operating Segments | Power Generation | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue										5,630		5,344		5,390
Depreciation and amortization										533		547		488
Interest income										9		15
Interest and related charges										250		232		219
Income tax expense (benefit)										220		534		524
Net income										1,008		939		909
Capital expenditures										1,003		1,290		$ 1,336
Total assets		19.4				18.6				19.4		18.6
Total assets		$ 19.4				$ 18.6				$ 19.4		$ 18.6
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to related parties.
[3]	See Note 24 for amounts attributable to affiliates.

Quarterly Financial and Common

Quarterly Financial and Common Stock Data (Unaudited) (Quarterly Financial and Common Stock Data) (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018		Dec. 31, 2017		Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Operating revenue	$ 3,361	$ 3,451	$ 3,088	$ 3,466	$ 3,210	$ 3,179	$ 2,813	$ 3,384	$ 13,366	[1]	$ 12,586	[1]	$ 11,737	[1]
Income (loss) from operations	834	1,150	742	875	953	1,152	753	1,079	3,601		3,937		3,448
Net income including noncontrolling interests	662	883	478	526	1,333	696	417	674	2,549		3,120		2,212
Net income	$ 641	$ 854	$ 449	$ 503	$ 1,312	$ 665	$ 390	$ 632	$ 2,447		$ 2,999		$ 2,123
Net income attributable to Dominion Energy - Basic	$ 0.97	$ 1.31	$ 0.69	$ 0.77	$ 2.04	$ 1.03	$ 0.62	$ 1.01	$ 3.74		$ 4.72		$ 3.44
Net income attributable to Dominion Energy - Diluted	0.97	1.30	0.69	0.77	2.04	1.03	0.62	1.01	3.74		4.72		3.44
Dividends declared per common share	$ 0.835	$ 0.835	$ 0.835	$ 0.835	$ 0.770	$ 0.770	$ 0.755	$ 0.755	$ 3.34		$ 3.035		$ 2.80
Virginia Electric and Power Company
Condensed Financial Statements, Captions [Line Items]
Operating revenue	$ 1,810	$ 2,232	$ 1,829	$ 1,748	$ 1,824	$ 2,154	$ 1,747	$ 1,831	$ 7,619	[2]	$ 7,556	[2]	$ 7,588	[2]
Income (loss) from operations	418	756	533	364	619	847	613	653	2,071		2,732		2,350
Net income	239	520	339	184	407	459	318	356	1,282		1,540		1,218
Dominion Energy Gas Holdings, LLC
Condensed Financial Statements, Captions [Line Items]
Operating revenue	532	423	459	526	501	401	422	490	1,940	[3]	1,814	[3]	1,638	[3]
Income (loss) from operations	(55)	182	7	201	181	185	116	156	335		638		593
Net income	$ (16)	$ 136	$ 15	$ 166	$ 313	$ 117	$ 77	$ 108	$ 301		$ 615		$ 392
[1]	See Note 9 for amounts attributable to related parties.
[2]	See Note 24 for amounts attributable to affiliates.
[3]	See Note 24 for amounts attributable to related parties.

Quarterly Financial and Commo_2

Quarterly Financial and Common Stock Data (Unaudited) (Narrative) (Detail) - USD ($) $ in Millions	3 Months Ended				12 Months Ended
	Dec. 31, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Parent Company Only Financial Information [Line Items]
After-tax gains from the sale of certain merchant generation facilities	$ 536
After-tax impairment charge for certain gathering and processing assets	164
After-taxcharge for disallowance of FERC-regulated plant		$ 89
After-taxcharge associated with Virginia legislation			$ 160
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act				$ (851)	$ 46	$ (851)	$ 0
Charges associated with equity method investments in wind-powered generation facilities, after tax						96
Virginia Electric and Power Company
Parent Company Only Financial Information [Line Items]
After-taxcharge associated with Virginia legislation			$ 160
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act				(93)	21	(93)	0
Dominion Energy Gas Holdings, LLC
Parent Company Only Financial Information [Line Items]
After-tax gains from the sale of certain merchant generation facilities	$ 165
After-taxcharge for disallowance of FERC-regulated plant		$ 89
Tax benefit resulting from remeasurement of deferred income taxes as a result of the 2017 Tax Reform Act				$ (197)	$ (11)	$ (197)	$ 0