Dominion Energy Gas 10-Q 2 Aug 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 13, 2018
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Trading Symbol	D
Entity Registrant Name	DOMINION ENERGY INC /VA/
Entity Central Index Key	715,957
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		653,765,671
Virginia Electric and Power Company
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Trading Symbol	VEL - PE
Entity Registrant Name	VIRGINIA ELECTRIC & POWER CO
Entity Central Index Key	103,682
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		274,723
Dominion Energy Gas Holdings, LLC
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Entity Registrant Name	Dominion Energy Gas Holdings, LLC
Entity Central Index Key	1,603,291
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0

Consolidated Statements of Inco

Consolidated Statements of Income (Unaudited) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating Revenue	[1]	$ 3,088	$ 2,813	$ 6,554	$ 6,197
Operating Expenses
Purchased (excess) electric capacity		23	(12)	37	(29)
Purchased gas		64	112	404	417
Other operations and maintenance		1,007	827	1,803	1,611
Depreciation and amortization		463	467	961	936
Other taxes		166	168	365	357
Total operating expenses		2,346	2,060	4,937	4,365
Income from operations		742	753	1,617	1,832
Other income		185	108	285	270
Interest and related charges		361	308	675	600
Income from operations before income tax expense		566	553	1,227	1,502
Income tax expense		88	136	223	411
Net Income Including Noncontrolling Interests		478	417	1,004	1,091
Noncontrolling Interests		29	27	52	69
Net Income		$ 449	$ 390	$ 952	$ 1,022
Earnings Per Common Share
Net income attributable to Dominion Energy - Basic		$ 0.69	$ 0.62	$ 1.46	$ 1.63
Net income attributable to Dominion Energy - Diluted		0.69	0.62	1.46	1.63
Dividends Declared Per Common Share		$ 0.8350	$ 0.7550	$ 1.670	$ 1.510
Virginia Electric and Power Company
Operating Revenue	[2]	$ 1,829	$ 1,747	$ 3,577	$ 3,578
Operating Expenses
Purchased (excess) electric capacity		23	(12)	37	(29)
Affiliated suppliers		74	75	157	153
Other		365	304	681	600
Depreciation and amortization		247	280	544	566
Other taxes		79	78	162	157
Total operating expenses		1,296	1,134	2,680	2,312
Income from operations		533	613	897	1,266
Other income		21	13	24	44
Interest and related charges	[2]	126	125	258	245
Income from operations before income tax expense		428	501	663	1,065
Income tax expense		89	183	140	391
Net Income		339	318	523	674
Dominion Energy Gas Holdings, LLC
Operating Revenue	[3]	459	422	985	912
Operating Expenses
Purchased gas	[3]		38	29	81
Other energy-related purchases		31	2	62	7
Affiliated suppliers		26	20	49	45
Other		295	148	418	301
Depreciation and amortization		53	56	112	110
Other taxes		47	43	107	97
Total operating expenses		452	307	777	641
Income from operations		7	115	208	271
Earnings from equity method investee		5	4	14	11
Other income		32	27	65	52
Interest and related charges	[3]	26	24	51	47
Income from operations before income tax expense		18	122	236	287
Income tax expense		3	45	55	102
Net Income		15	77	181	185
Electric Fuel and Other Energy-Related Purchases
Operating Expenses
Electric fuel and other energy-related purchases		623	498	1,367	1,073
Electric Fuel and Other Energy-Related Purchases | Virginia Electric and Power Company
Operating Expenses
Electric fuel and other energy-related purchases	[2]	$ 508	$ 409	$ 1,099	$ 865
[1]	See Note 10 for amounts attributable to related parties.
[2]	See Note 18 for amounts attributable to affiliates.
[3]	See Note 18 for amounts attributable to related parties.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net income including noncontrolling interests		$ 478	$ 417	$ 1,004	$ 1,091
Net income		449	390	952	1,022
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[1]	(33)	28	78	71
Changes in unrealized net gains (losses) on investment securities	[2]	(5)	35	(18)	93
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[3]	33	(18)	41	(41)
Net realized (gains) losses on investment securities	[4]		(4)	1	(32)
Net pension and other postretirement benefit costs	[5]	17	11	42	24
Changes in other comprehensive income from equity method investees	[6]	1	1	1	2
Total other comprehensive income (loss)		13	53	145	117
Comprehensive income including noncontrolling interests		491	470	1,149	1,208
Comprehensive income attributable to noncontrolling interests		29	27	53	69
Comprehensive income		462	443	1,096	1,139
Virginia Electric and Power Company
Net income		339	318	523	674
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[7]	2	(3)	7	(3)
Changes in unrealized net gains (losses) on investment securities	[8]	(2)	4	(2)	11
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[9]		1		1
Net realized (gains) losses on nuclear decommissioning trust funds	[10]		(1)		(4)
Total other comprehensive income (loss)			1	5	5
Comprehensive income		339	319	528	679
Dominion Energy Gas Holdings, LLC
Net income		15	77	181	185
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[11]	(20)	11	(7)	2
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[12]	14	(12)	11	(1)
Net pension and other postretirement benefit costs	[13]	1	2	2	2
Total other comprehensive income (loss)		(5)	1	6	3
Comprehensive income		$ 10	$ 78	$ 187	$ 188
[1]	Net of $11 million and $(17) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(26) million and $(44) million tax for the six months ended June 30, 2018 and 2017, respectively.
[2]	Net of $2 million and $(18) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $6 million and $(53) million tax for the six months ended June 30, 2018 and 2017, respectively.
[3]	Net of $(11) million and $11 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(14) million and $25 million tax for the six months ended June 30, 2018 and 2017, respectively.
[4]	Net of $(1) million and $2 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million and $18 million tax for the six months ended June 30, 2018 and 2017, respectively.
[5]	Net of $(7) million and $(10) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(8) million and $(18) million tax for the six months ended June 30, 2018 and 2017, respectively.
[6]	Net of $(1) million and $— million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million tax for both the six months ended June 30, 2018 and 2017.
[7]	Net of $— million and $2 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(2) million and $2 million tax for the six months ended June 30, 2018 and 2017, respectively.
[8]	Net of $— million and $(3) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $1 million and $(7) million tax for the six months ended June 30, 2018 and 2017, respectively.
[9]	Net of $— million tax for both the three and six months ended June 30, 2018 and 2017.
[10]	Net of $— million tax for both the three months ended June 30, 2018 and 2017, and net of $— million and $2 million tax for the six months ended June 30, 2018 and 2017, respectively.
[11]	Net of $7 million and $(7) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $3 million and $(1) million tax for the six months ended June 30, 2018 and 2017, respectively.
[12]	Net of $(5) million and $7 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(4) million and $— million tax for the six months ended June 30, 2018 and 2017, respectively.
[13]	Net of $— million tax for both the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million tax for both the six months ended June 30, 2018 and 2017.

Consolidated Statements of Com4

Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net deferred gains (losses) on derivative-hedging activities, tax	$ 11	$ (17)	$ (26)	$ (44)
Changes in unrealized net gains (losses) on investment securities, tax	2	(18)	6	(53)
Net derivative (gains) losses-hedging activities, tax	(11)	11	(14)	25
Net realized gains on investment securities, tax	(1)	2	(1)	18
Net pension and other postretirement benefit costs, tax	(7)	(10)	(8)	(18)
Changes in other comprehensive income (loss) from equity method investees, tax	(1)		(1)	(1)
Virginia Electric and Power Company
Net deferred gains (losses) on derivative-hedging activities, tax		2	(2)	2
Changes in unrealized net gains (losses) on investment securities, tax		(3)	1	(7)
Net realized (gains) losses on nuclear decommissioning trust funds, tax				2
Dominion Energy Gas Holdings, LLC
Net deferred gains (losses) on derivative-hedging activities, tax	7	(7)	3	(1)
Net derivative (gains) losses-hedging activities, tax	$ (5)	$ 7	(4)
Net pension and other postretirement benefit costs, tax			$ (1)	$ (1)

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions		Jun. 30, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents		$ 190	$ 120	[1]
Customer receivables (less allowance for doubtful accounts)		1,510	1,660	[1]
Other receivables (less allowance for doubtful accounts)	[2]	133	126	[1]
Inventories		1,429	1,477	[1]
Regulatory assets	[3]	616	294	[1]
Other		732	657	[1]
Total current assets		4,610	4,334	[1]
Investments
Nuclear decommissioning trust funds		5,159	5,093	[1]
Investment in equity method affiliates		1,710	1,544	[1]
Other		339	327	[1]
Total investments		7,208	6,964	[1]
Property, Plant and Equipment
Property, plant and equipment		76,458	74,823	[1]
Accumulated depreciation, depletion and amortization		(21,854)	(21,065)	[1]
Total property, plant and equipment, net		54,604	53,758	[1]
Deferred Charges and Other Assets
Goodwill		6,405	6,405	[1]
Regulatory assets		2,395	2,480	[1]
Other		2,853	2,644	[1]
Total deferred charges and other assets		11,653	11,529	[1]
Total assets		78,075	76,585	[1]
Current Liabilities
Securities due within one year		2,950	3,078	[1]
Short-term debt		2,745	3,298	[1]
Accounts payable		660	875	[1]
Regulatory liabilities	[4]	424	193
Other	[2]	2,563	2,385	[1]
Total current liabilities		8,918	9,636	[1]
Long-Term Debt
Long-term debt		26,679	25,588	[1]
Junior subordinated notes		3,981	3,981	[1]
Remarketable subordinated notes		1,382	1,379	[1]
Credit facility borrowings		73
Total long-term debt		32,115	30,948	[1]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,844	4,523	[1]
Regulatory liabilities		7,065	6,916	[1]
Other	[2]	5,097	5,192	[1]
Total deferred credits and other liabilities		17,006	16,631	[1]
Total liabilities		58,039	57,215	[1]
Commitments and Contingencies				[1]
Equity
Common stock – no par	[5]	10,782	9,865	[1]
Retained earnings		8,820	7,936	[1]
Accumulated other comprehensive loss		(1,538)	(659)	[1]
Total common shareholders' equity		18,064	17,142	[1]
Noncontrolling interests		1,972	2,228	[1]
Total equity		20,036	19,370	[1]
Total liabilities and equity		78,075	76,585	[1]
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents		20	14	[6]
Customer receivables (less allowance for doubtful accounts)		994	951	[6]
Other receivables (less allowance for doubtful accounts)		46	64	[6]
Affiliated receivables		73	3	[6]
Inventories		814	850	[6]
Regulatory assets	[3]	552	205	[6]
Other	[7]	169	137	[6]
Total current assets		2,668	2,224	[6]
Investments
Nuclear decommissioning trust funds		2,449	2,399	[6]
Other		4	3	[6]
Total investments		2,453	2,402	[6]
Property, Plant and Equipment
Property, plant and equipment		43,444	42,329	[6]
Accumulated depreciation, depletion and amortization		(13,683)	(13,277)	[6]
Total property, plant and equipment, net		29,761	29,052	[6]
Deferred Charges and Other Assets
Regulatory assets		729	810	[6]
Other	[7]	719	651	[6]
Total deferred charges and other assets		1,448	1,461	[6]
Total assets		36,330	35,139	[6]
Current Liabilities
Securities due within one year	[6]		850
Short-term debt		1,158	542	[6]
Accounts payable		296	361	[6]
Payables to affiliates		109	125	[6]
Affiliated current borrowings		25	33	[6]
Regulatory liabilities		305	127
Other	[7]	1,321	1,009	[6]
Total current liabilities		2,909	2,920	[6]
Long-Term Debt
Total long-term debt		11,091	10,496	[6]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,894	2,728	[6]
Asset retirement obligations		1,302	1,149	[6]
Regulatory liabilities		4,877	4,760	[6]
Other	[7]	760	862	[6]
Total deferred credits and other liabilities		9,833	9,499	[6]
Total liabilities		23,833	22,915	[6]
Commitments and Contingencies				[6]
Equity
Common stock – no par	[8]	5,738	5,738	[6]
Other paid-in capital		1,113	1,113	[6]
Retained earnings		5,655	5,311	[6]
Accumulated other comprehensive loss		(9)	62	[6]
Total common shareholders' equity		12,497	12,224	[6]
Total liabilities and equity		36,330	35,139	[6]
Dominion Energy Gas Holdings, LLC
Current Assets
Cash and cash equivalents		5	4	[9]
Customer receivables (less allowance for doubtful accounts)	[10]	223	297	[9]
Other receivables (less allowance for doubtful accounts)	[10]	22	15	[9]
Affiliated receivables		31	10	[9]
Inventories		82	64	[9]
Gas imbalances	[10]	62	46	[9]
Prepayments		86	112	[9]
Regulatory assets	[3]	35	26
Other		60	52	[9]
Total current assets		571	600	[9]
Investments
Total investments		97	97	[9]
Property, Plant and Equipment
Property, plant and equipment		11,341	11,173	[9]
Accumulated depreciation, depletion and amortization		(3,111)	(3,018)	[9]
Total property, plant and equipment, net		8,230	8,155	[9]
Deferred Charges and Other Assets
Pension and other postretirement benefit assets	[10]	1,907	1,828	[9]
Regulatory assets	[11]	526	511
Other	[10]	1,278	1,260	[9]
Total deferred charges and other assets		3,185	3,088	[9]
Total assets		12,083	11,940	[9]
Current Liabilities
Short-term debt		188	629	[9]
Accounts payable		97	193	[9]
Payables to affiliates		15	62	[9]
Affiliated current borrowings		56	18	[9]
Regulatory liabilities	[4]	48	38
Other	[10]	406	439	[9]
Total current liabilities		762	1,341	[9]
Long-Term Debt
Total long-term debt		4,062	3,570	[9]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		1,489	1,454	[9]
Regulatory liabilities		1,253	1,227	[9]
Other		189	185	[9]
Total deferred credits and other liabilities		2,931	2,866	[9]
Total liabilities		7,755	7,777	[9]
Commitments and Contingencies				[9]
Equity
Membership interests		4,446	4,261	[9]
Accumulated other comprehensive loss		(118)	(98)	[9]
Total equity		4,328	4,163	[9]
Total liabilities and equity		$ 12,083	$ 11,940	[9]
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	See Note 10 for amounts attributable to related parties.
[3]	Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.
[4]	Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets.
[5]	1 billion shares authorized; 654 million shares and 645 million shares outstanding at June 30, 2018 and December 31, 2017, respectively.
[6]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[7]	See Note 18 for amounts attributable to affiliates.
[8]	500,000 shares authorized; 274,723 shares outstanding at June 30, 2018 and December 31, 2017.
[9]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[10]	See Note 18 for amounts attributable to related parties.
[11]	Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.

Consolidated Balance Sheets (U6

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions		Jun. 30, 2018	Dec. 31, 2017
Customer receivables, allowance for doubtful accounts		$ 19	$ 17
Other receivables, allowance for doubtful accounts	[1]	$ 3	$ 2
Common stock, shares authorized		1,000,000,000	1,000,000,000
Common stock, shares outstanding		654,000,000	645,000,000
Virginia Electric and Power Company
Customer receivables, allowance for doubtful accounts		$ 10	$ 10	[2]
Other receivables, allowance for doubtful accounts		$ 1	$ 1	[2]
Common stock, shares authorized		500,000	500,000	[2]
Common stock, shares outstanding		274,723	274,723	[2]
Dominion Energy Gas Holdings, LLC
Customer receivables, allowance for doubtful accounts	[3],[4]		$ 1
Other receivables, allowance for doubtful accounts	[4]	$ 1	$ 1	[3]
Dominion Energy Gas Holdings, LLC | Maximum
Customer receivables, allowance for doubtful accounts	[4]	$ 1
[1]	See Note 10 for amounts attributable to related parties.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[4]	See Note 18 for amounts attributable to related parties.

Consolidated Statements of Equi

Consolidated Statements of Equity (Unaudited) - USD ($) $ in Millions	Total		Virginia Electric and Power Company		Dominion Energy Gas Holdings, LLC		Common Stock	Common StockVirginia Electric and Power Company	Retained Earnings	Retained EarningsVirginia Electric and Power Company	AOCI	AOCIVirginia Electric and Power Company	AOCIDominion Energy Gas Holdings, LLC	Total Common Shareholders' Equity	Noncontrolling Interests	Other Paid-In CapitalVirginia Electric and Power Company	Member UnitsDominion Energy Gas Holdings, LLC
Beginning balance at Dec. 31, 2016	$ 16,840						$ 8,550		$ 6,854		$ (799)			$ 14,605	$ 2,235
Beginning balance (in shares) at Dec. 31, 2016							628,000,000
Beginning balance at Dec. 31, 2016											(799)	$ 46	$ (123)
Net income including noncontrolling interests	1,091								1,022					1,022	69
Net income	1,022		$ 674		$ 185
Contributions from NRG to Four Brothers and Three Cedars	9														9
Issuance of common stock	156						$ 156							156
Issuance of common stock (in shares)			0				2,000,000
Stock awards (net of change in unearned compensation)	11						$ 11							11
Dividends and distributions	(1,031)								(949)					(949)	(82)
Other comprehensive income, net of tax	117		$ 5		3						117	5	3	117
Other	12								11					11	1
Ending balance at Jun. 30, 2017	17,205						$ 8,717		6,938		(682)			14,973	2,232
Ending balance (in shares) at Jun. 30, 2017							630,000,000
Ending balance at Jun. 30, 2017											(682)	51	(120)
Beginning balance at Mar. 31, 2017											(735)	50	(121)
Net income	390		$ 318		77
Issuance of common stock (in shares)			0
Other comprehensive income, net of tax	53		$ 1		1							1	1
Ending balance at Jun. 30, 2017	17,205						$ 8,717		6,938		(682)			14,973	2,232
Ending balance (in shares) at Jun. 30, 2017							630,000,000
Ending balance at Jun. 30, 2017											(682)	51	(120)
Beginning balance at Dec. 31, 2017	19,370	[1]					$ 9,865		7,936		(659)			17,142	2,228
Beginning balance (in shares) at Dec. 31, 2017							645,000,000	275,000,000
Beginning balance at Dec. 31, 2017	17,142	[1]	12,224	[2]				$ 5,738		$ 5,311	(659)	62	(98)			$ 1,113
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	1,004								952					952	52
Net income	952		$ 523		181					523							181
Issuance of common stock	662						$ 662							662
Issuance of common stock (in shares)			0				9,000,000
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)	12						12							12
Dividends and distributions	(1,154)		$ (257)						(1,089)	(257)				(1,089)	(65)
Distributions					(25)												(25)
Other comprehensive income, net of tax	145		5		6						144	5	6	144	1
Other	(13)		(1)				(5)		(8)	(1)				(13)
Ending balance at Jun. 30, 2018	20,036						$ 10,782		8,820		(1,538)			18,064	1,972
Ending balance (in shares) at Jun. 30, 2018							654,000,000	275,000,000
Ending balance at Jun. 30, 2018	18,064		12,497					$ 5,738		5,655	(1,538)	(9)	(118)			1,113
Beginning balance at Dec. 31, 2017					4,163	[3]							(98)				4,261
Ending balance at Jun. 30, 2018					4,328								(118)				4,446
Beginning balance at Mar. 31, 2018											(1,551)	(9)	(113)
Net income	449		$ 339		15
Issuance of common stock (in shares)			0
Other comprehensive income, net of tax	13				(5)								(5)
Ending balance at Jun. 30, 2018	20,036						$ 10,782		$ 8,820		(1,538)			$ 18,064	$ 1,972
Ending balance (in shares) at Jun. 30, 2018							654,000,000	275,000,000
Ending balance at Jun. 30, 2018	$ 18,064		$ 12,497					$ 5,738		$ 5,655	$ (1,538)	$ (9)	(118)			$ 1,113
Ending balance at Jun. 30, 2018					$ 4,328								$ (118)				$ 4,446
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Operating Activities
Net income including noncontrolling interests	$ 1,004	$ 1,091
Net income	952	1,022
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	1,106	1,088
Deferred income taxes and investment tax credits	229	406
Proceeds from assignment of tower rental portfolio		91
Contribution to pension plan		(75)
Gains on sales of assets	(44)
Provision for rate credits to electric utility customers	215
Charge associated with future ash pond and landfill closure costs	81
Charge associated with FERC-regulated plant disallowance	129
Other adjustments	(42)	(64)
Changes in:
Accounts receivable	158	307
Inventories	31	21
Deferred fuel and purchased gas costs, net	(295)	(79)
Prepayments	(15)	32
Accounts payable	(151)	(211)
Accrued interest, payroll and taxes	(90)	(73)
Customer deposits	108	12
Margin deposit assets and liabilities	(34)	54
Net realized and unrealized changes related to derivative activities	82	34
Other operating assets and liabilities	(47)	(274)
Net cash provided by operating activities	2,425	2,360
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(2,046)	(2,748)
Proceeds from assignments of shale development rights	44
Acquisition of solar development projects	(51)	(280)
Proceeds from sales of securities	844	1,119
Purchases of securities	(890)	(1,156)
Contributions to equity method affiliates	(134)	(252)
Other	(3)	(4)
Net cash used in investing activities	(2,236)	(3,321)
Financing Activities
Issuance of short-term notes	1,450
Issuance (repayment) of short-term debt, net	(553)	(322)
Issuance of long-term debt	2,400	2,730
Repayment of long-term debt	(2,840)	(490)
Credit facility borrowings	73
Issuance of common stock	662	156
Common dividend payments	(1,089)	(949)
Other	(123)	(162)
Net cash provided by (used in) financing activities	(20)	963
Increase in cash, restricted cash and equivalents	169	2
Cash, restricted cash and equivalents at beginning of period	185	322
Cash, restricted cash and equivalents at end of period	354	324
Significant noncash investing and financing activities:
Accrued capital expenditures	253	270
Virginia Electric and Power Company
Operating Activities
Net income	523	674
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	632	665
Deferred income taxes and investment tax credits	137	167
Proceeds from assignment of tower rental portfolio		91
Provision for rate credits to customers	215
Charge associated with future ash pond and landfill closure costs	81
Other adjustments	(19)	(20)
Changes in:
Accounts receivable	(26)	92
Affiliated receivables and payables	(86)	39
Inventories	36	19
Deferred fuel and purchased gas costs, net	(357)	(78)
Prepayments	(6)	(4)
Accounts payable	(45)	(32)
Accrued interest, payroll and taxes	13	23
Net realized and unrealized changes related to derivative activities	54	27
Asset retirement obligations	(18)	(42)
Other operating assets and liabilities	64	(130)
Net cash provided by operating activities	1,198	1,491
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(1,170)	(1,216)
Purchases of nuclear fuel	(55)	(116)
Acquisition of solar development projects	(43)	(3)
Proceeds from sales of securities	414	498
Purchases of securities	(436)	(517)
Other	4	(17)
Net cash used in investing activities	(1,286)	(1,371)
Financing Activities
Issuance (repayment) of short-term debt, net	616	351
Issuance of long-term debt	700	750
Repayment of affiliated current borrowings, net	(8)	(250)
Repayment of long-term debt	(951)	(78)
Common dividend payments	(257)	(854)
Other	(6)	(6)
Net cash provided by (used in) financing activities	94	(87)
Increase in cash, restricted cash and equivalents	6	33
Cash, restricted cash and equivalents at beginning of period	24	11
Cash, restricted cash and equivalents at end of period	30	44
Significant noncash investing and financing activities:
Accrued capital expenditures	159	169
Dominion Energy Gas Holdings, LLC
Operating Activities
Net income	181	185
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	112	110
Deferred income taxes and investment tax credits	27	112
Gains on sales of assets	(44)
Charge associated with FERC-regulated plant disallowance	129
Other adjustments	4	(6)
Changes in:
Accounts receivable	67	73
Inventories	(18)	(12)
Deferred fuel and purchased gas costs, net	8	11
Prepayments	26	18
Accounts payable	(101)	(97)
Accrued interest, payroll and taxes	(51)	(52)
Other operating assets and liabilities	7	(3)
Affiliated receivables and payables	(68)	(19)
Asset retirement obligations	(72)	(65)
Net cash provided by operating activities	207	255
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(316)	(309)
Proceeds from assignments of shale development rights	44
Other	(6)	(1)
Net cash used in investing activities	(278)	(310)
Financing Activities
Issuance (repayment) of short-term debt, net	(441)	155
Issuance of long-term debt	500
Repayment of affiliated current borrowings, net	38	(94)
Distribution payments to parent	(25)	(15)
Other	(2)
Net cash provided by (used in) financing activities	70	46
Increase in cash, restricted cash and equivalents	(1)	(9)
Cash, restricted cash and equivalents at beginning of period	30	43
Cash, restricted cash and equivalents at end of period	29	34
Significant noncash investing and financing activities:
Accrued capital expenditures	$ 51	$ 44

Nature of Operations

Nature of Operations	6 Months Ended
	Jun. 30, 2018
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Nature of Operations	Note 1. Nature of Operations 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. 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 and Midwest states, regulated gas transportation and distribution operations in Ohio, and gas gathering and processing activities primarily in West Virginia, Ohio and Pennsylvania. In addition, other Dominion Energy subsidiaries provide merchant generation, LNG terminalling services, natural gas transmission and distribution services primarily in the eastern and Rocky Mountain regions of the U.S.

Significant Accounting Policies

Significant Accounting Policies	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Significant Accounting Policies	Note 2. Significant Accounting Policies As permitted by the rules and regulations of the SEC, the Companies’ accompanying unaudited Consolidated Financial Statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of June 30, 2018, their results of operations for the three and six months ended June 30, 2018 and 2017, their cash flows for the six months ended June 30, 2018 and 2017, Dominion Energy’s changes in equity for the six months ended June 30, 2018 and 2017 and Virginia Power and Dominion Energy Gas’ changes in equity for the six months ended June 30, 2018. Such adjustments are normal and recurring in nature unless otherwise noted. The Companies make certain estimates and assumptions in preparing their Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates. The Companies’ accompanying unaudited Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned entities in which they have a controlling financial interest. For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. At June 30, 2018, Dominion Energy owns the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy Midstream. The public’s ownership interest in Dominion Energy Midstream is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Also, at June 30, 2018, Dominion Energy owns 50% of the units in and consolidates Four Brothers and Three Cedars. NRG’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy merchant solar projects, is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Terra Nova Renewable Partners has a future option to buy all or a portion of Dominion Energy’s remaining 67% ownership in the projects upon the occurrence of certain events, none of which had occurred at June 30, 2018 nor are expected to occur in the remainder of 2018. The results of operations for interim periods are not necessarily indicative of the results expected for the full year. Information for quarterly periods is affected by seasonal variations in sales, rate changes, electric fuel and other energy-related purchases, purchased gas expenses and other factors. Certain amounts in the Companies’ 2017 Consolidated Financial Statements and Notes have been reclassified as a result of the adoption of revised accounting guidance pertaining to certain net periodic pension and other postretirement benefit costs, restricted cash and equivalents and certain distributions from equity method investees. In addition, certain other amounts 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. The effects of the adoption of new accounting standards on the Consolidated Financial Statements are described below. With the exception of the property, plant and equipment item described below, there have been no other significant changes from Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. 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 include accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to utility customers. Virginia Power’s customer receivables include accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to customers. Dominion Energy Gas’ customer receivables include accrued unbilled revenue based on estimated amounts of natural gas delivered and services provided but not yet billed to customers. 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: Revenue from Contracts with Customers • Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated hedging activity; • Regulated gas sales consist primarily of state-regulated natural gas sales and related distribution services; • Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties and associated hedging activity; • Regulated gas transportation and storage sales consist of FERC-regulated sales of transmission and storage services and state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • Nonregulated gas transportation and storage sales consist primarily of LNG terminalling services; • Other regulated revenue consists primarily of miscellaneous service revenue from electric and gas distribution operations and sales of excess electric capacity and other commodities; and • Other nonregulated revenue consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity. Other nonregulated revenue also includes services performed for Atlantic Coast Pipeline, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations, service concession arrangements and gas processing and handling revenue. Other Revenue • Other revenue consists primarily of alternative revenue programs, gains and losses from derivative instruments not subject to hedge accounting and lease revenues. 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 consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Nonregulated electric sales consisted primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity; • Regulated gas sales consisted primarily of state- and FERC-regulated natural gas sales and related distribution services and associated derivative activity; • Nonregulated gas sales consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity; • Gas transportation and storage sales consisted primarily of FERC-regulated sales of transmission and storage services. Also included were state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; and • Other revenue consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also included miscellaneous service revenue from electric and gas distribution operations, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations and gas processing and handling 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: Revenue from Contracts with Customers • Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Other regulated revenue consists primarily of sales of excess capacity and other commodities and miscellaneous service revenue from electric distribution operations; and • Other nonregulated revenue consists primarily of sales to non-jurisdictional customers from certain solar facilities, revenue from renting space on certain electric transmission poles and distribution towers and service concession arrangements. Other Revenue • Other revenue consists primarily of alternative revenue programs and gains and losses from derivative instruments not subject to hedge accounting. 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 consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; and • Other revenue consisted primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities. The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: Revenue from Contracts with Customers • Regulated gas sales consist primarily of state-regulated natural gas sales and related distribution services; • Nonregulated gas sales consist primarily of sales of gas purchased from third parties and royalty revenues; • Regulated gas transportation and storage sales consist of FERC-regulated sales of transmission and storage services and state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • NGL revenue consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity; • Management service revenue consists primarily of services performed for Atlantic Coast Pipeline; • Other regulated revenue consists primarily of miscellaneous regulated revenues; and • Other nonregulated revenue consists primarily of miscellaneous service revenue. Other Revenue • Other revenue consists primarily of gains and losses from derivative instruments not subject to hedge accounting. 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 consisted primarily of state- and FERC-regulated natural gas sales and related distribution services; • Nonregulated gas sales consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices and sales of gas purchased from third parties. Revenue from sales of gas production was recognized based on actual volumes of gas sold to purchasers and was reported net of royalties; • Gas transportation and storage sales consisted primarily of FERC-regulated sales of transmission and storage services. Also included were state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • NGL revenue consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity; and • Other revenue consisted primarily of miscellaneous service revenue, gas processing and handling revenue. 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. Currently, Dominion Energy and Virginia Power account for the equity return for under-recovery of certain riders under the alternative revenue program guidance. 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 phase of the Liquefaction Project. Fixed fees are recognized ratably over the life of the contract as the stand-ready performance obligation is satisfied, while variable usage fees are recognized when Dominion Energy and Dominion Energy Gas have a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the performance obligation completed to date. Sales of products, such as NGLs, typically transfer control and are recognized as revenue upon delivery of the product. The customer is able to direct the use of, and obtain substantially all of the benefits from, the product at the time the product is delivered. The contract with the customer states the final terms of the sale, including the description, quantity and price of each product or service purchased. Payment for most sales and services varies by contract type, but is typically due within a month of billing. 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. Cash, Restricted Cash and Equivalents Restricted Cash and Equivalents The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for certain customer deposits, future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements and a distribution reserve at Cove Point. Upon adoption of revised accounting guidance in January 2018, restricted cash and equivalents are included within the Companies’ Consolidated Statements of Cash Flows, with the change in balance no longer considered a separate investing activity. The guidance required retrospective application which resulted in an adjustment to Dominion Energy and Dominion Energy Gas’ other cash provided by (used in) investing activities for the six months ended June 30, 2017, which had been previously reported as $4 million and $(11) million, respectively. There was no impact to Virginia Power for the six months ended June 30, 2017. 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 six months ended June 30, 2018 and 2017: Cash, Restricted Cash and Equivalents at End of Period Cash, Restricted Cash and Equivalents at Beginning of Period June 30, 2018 June 30, 2017 December 31, 2017 December 31, 2016 (millions) Dominion Energy Cash and cash equivalents $ 190 $ 260 $ 120 $ 261 Restricted cash and equivalents (1) 164 64 65 61 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 354 $ 324 $ 185 $ 322 Virginia Power Cash and cash equivalents $ 20 $ 44 $ 14 $ 11 Restricted cash and equivalents (1) 10 — 10 — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 30 $ 44 $ 24 $ 11 Dominion Energy Gas Cash and cash equivalents $ 5 $ 4 $ 4 $ 23 Restricted cash and equivalents (1) 24 30 26 20 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 29 $ 34 $ 30 $ 43 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets. Distributions from Equity Method Investees Dominion Energy and Dominion Energy Gas each hold investments that are accounted for under the equity method of accounting. Effective January 2018, 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. Previously, distributions were determined to be either a return on an investment or return of an investment based on a cumulative earnings approach whereby any distributions received in excess of earnings were considered to be a return of an investment. Dominion Energy and Dominion Energy Gas have applied this approach on a retrospective basis. As a result, distributions from equity method investees were reclassified within Dominion Energy’s Consolidated Statement of Cash Flows between distributions from equity method affiliates to other adjustments from operating activities, which were previously reported as $(72) million for the six months ended June 30, 2017. There was no impact to Dominion Energy Gas for the six months ended June 30, 2017. Property, Plant and Equipment 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 $46 million ($36 million after-tax) in depreciation expense in Virginia Power’s Consolidated Statements of Income. This revision is expected to decrease annual depreciation expense by approximately $30 million ($23 million after-tax). Investments Debt and Equity Securities with Readily Determinable Fair Values Dominion Energy accounts for and classifies investments in debt securities as trading or available-for-sale securities. Virginia Power classifies investments in debt securities as available-for-sale securities. • Debt securities classified as trading securities include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income. • Debt securities classified as available-for-sale securities include all other debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power’s nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale debt securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax. In determining realized gains and losses for 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. Equity Securities without Readily Determinable Fair Values 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 when the Companies have the ability to exercise significant influence, but not control, over the investee. Dominion Energy’s investments are included in investments in equity method affiliates and Dominion Energy Gas’ investments are included in investments in their Consolidated Balance Sheets. Dominion Energy and Dominion Energy Gas record equity method adjustments in other income and earnings from equity method investee, respectively, in their Consolidated Statements of Income, including their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method. • Cost method investments when Dominion Energy and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion Energy’s and Virginia Power’s investments are included in other investments and nuclear decommissioning trust funds. Cost method investments are reported at cost less impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for identical or similar investments of the same issuer. Other-Than-Temporary Impairment 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 or 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 that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, Dominion Energy and Virginia Power record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors. New Accounting Standards Revenue Recognition 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 recorded offsetting operating revenue and other energy-related purchases of $25 million and $50 million in the Consolidated Statements of Income for non-cash consideration for performing processing and fractionation services related to NGLs for the three and six months ended June 30, 2018, respectively. No such amounts were recorded during the three and six months ended June 30, 2017. Dominion Energy and Dominion Energy Gas no longer record offsetting operating revenue and purchased gas for fuel retained to offset costs on certain transportation and storage arrangements. Such amounts at Dominion Energy were $31 million and $63 million, respectively, and Dominion Energy Gas were $24 million and $48 million, respectively, recorded in the Consolidated Statements of Income for the three and six months ended June 30, 2017. Financial Instruments 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) and $119 million ($73 million after-tax), respectively, of net unrealized gains from AOCI to retained earnings. Dominion Energy and Virginia Power also recorded approximately $36 million ($22 million after-tax) in net unrealized gains on equity securities previously classified as cost method investments, of which $3 million was recorded to retained earnings and $33 million was recorded to regulatory liabilities for net unrealized gains subject to cost-based regulation. As a result of adopting this revised accounting guidance, Dominion Energy recorded unrealized gains on equity securities, net of regulatory deferrals, of $45 million ($36 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax) in other income in the Consolidated Statements of Income for the three and six months ended June 30, 2018, respectively, resulting in a $0.06 gain per share for the three months ended June 30, 2018. There was no impact to per share amounts at Dominion Energy for the six months ended June 30, 2018. Virginia Power recorded unrealized gains on equity securities, net of regulatory deferrals, of $6 million ($5 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax), respectively, in other income in the Consolidated Statements of Income for the three and six months ended June 30, 2018. Derecognition and Partial Sales of Nonfinancial Assets 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. Net Periodic Pension and Other Postretirement Benefit Costs In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic pension and other postretirement benefit costs. The update 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 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. This guidance became effective for the Companies beginning January 1, 2018 with a retrospective adoption for income statement presentation and a prospective adoption for capitalization. Dominion Energy’s and Dominion Energy Gas’ Consolidated Statements of Income for the six months ended June 30, 2017 have been recast to reflect retrospective adoption for the presentation of the non-service cost component of net periodic pension and other postretirement benefit costs. Previously, the non-service cost component for Dominion Energy and Dominion Energy Gas was ref

Acquisitions and Dispositions

Acquisitions and Dispositions	6 Months Ended
	Jun. 30, 2018
Business Combinations Discontinued Operations And Disposal Groups [Abstract]
Acquisitions and Dispositions	Note 3. Acquisitions and Dispositions Dominion Energy Proposed Acquisition of SCANA Under the terms of the SCANA Merger Agreement announced in January 2018, Dominion Energy has agreed to issue 0.6690 shares of Dominion Energy common stock for each share of SCANA common stock upon closing. In addition, Dominion Energy will provide the financial support for SCE&G to make a $1.3 billion up-front, one-time rate credit to all current electric service customers of SCE&G to be paid within 90 days of closing and a $575 million refund along with the benefit of the 2017 Tax Reform Act resulting in an approximate 7% reduction to SCE&G electric service customers’ bills over an eight-year period as well as the exclusions from rate recovery of approximately $1.7 billion of costs related to the V.C. Summer Units 2 and 3 new nuclear development project and approximately $180 million to purchase the Columbia Energy Center power station. In addition, SCANA’s debt, which currently totals approximately $7.0 billion, is expected to remain outstanding. The transaction requires approval of SCANA’s shareholders, FERC, applicable state commissions and the NRC and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. In January 2018, SCANA and Dominion Energy filed for review and approval from the South Carolina Public Service Commission, the North Carolina Utilities Commission, the Georgia Public Service Commission and the NRC. In February 2018, the Federal Trade Commission granted early termination of the waiting period under the Hart-Scott-Rodino Act. Also in February 2018, Dominion Energy and SCANA filed for review and approval by FERC. In March 2018, the Georgia Public Service Commission approved the proposed merger. In July 2018, FERC and SCANA’s shareholders approved the proposed merger. Dominion Energy is not required to accept an order by the South Carolina Public Service Commission approving Dominion Energy’s merger with SCANA if such order contains any material change to the terms, conditions or undertakings set forth in the cost recovery plan related to the V.C. Summer Units 2 and 3 new nuclear development project or any significant changes to the economic value of the cost recovery plan. In addition, the SCANA Merger Agreement provides that Dominion Energy will have the right to refuse to close the merger if there shall have occurred any substantive change in the Base Load Review Act or other laws governing South Carolina public utilities which has or would reasonably be expected to have an adverse effect on SCE&G. The SCANA Merger Agreement contains certain termination rights for both Dominion Energy and SCANA, and provides that, upon termination of the SCANA Merger Agreement under specified circumstances, Dominion Energy would be required to pay a termination fee of $280 million to SCANA and SCANA would be required to pay Dominion Energy a termination fee of $240 million. Subject to receipt of required regulatory approvals and meeting closing conditions, Dominion Energy targets closing by the end of 2018. Wholly-Owned Merchant Solar Projects In August 2016, Dominion Energy entered into an agreement to acquire 100% of the equity interests of two solar projects in California from Solar Frontier Americas Holding LLC for cash consideration. In March 2017, Dominion Energy closed on the acquisition of one of the solar projects for $77 million, all of which was allocated to property, plant and equipment. The facility commenced commercial operations in June 2017, at a cost of $78 million, including the initial acquisition cost, and generates approximately 30 MW. In April 2017, Dominion Energy discontinued efforts on the acquisition of the additional 20 MW solar project from Solar Frontier Americas Holding LLC. In September 2016, Dominion Energy entered into an agreement to acquire 100% of the equity interests of a solar project in Virginia from Community Energy Solar, LLC for cash consideration. In February 2017, Dominion Energy closed on the acquisition for $29 million, all of which was allocated to property, plant and equipment. The facility commenced commercial operations in December 2017, at a cost of $205 million, including the initial acquisition cost, and generates approximately 100 MW. In January 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of a solar project in North Carolina from Cypress Creek Renewables, LLC for cash consideration. In May 2017, Dominion Energy closed on the acquisition for $154 million, all of which was allocated to property, plant and equipment. The facility commenced commercial operations in June 2017, at a cost of $160 million, including the initial acquisition cost, and generates approximately 79 MW. In May 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of two solar projects in Virginia from Hecate Energy Virginia C&C LLC for cash consideration of $56 million. Dominion Energy completed the acquisition of one of the projects in June 2017 for $16 million and the facility commenced commercial operations in August 2017. The second acquisition was completed in September 2017 for $40 million and the facility commenced commercial operations in November 2017. The projects cost $57 million, including initial acquisition costs, and generate approximately 30 MW combined. In June 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of four solar projects in North Carolina from Strata Solar Development, LLC and Moorings Farm 2 Holdco, LLC for cash consideration of $40 million. Dominion Energy completed the acquisition of two of the projects in June 2017 at a cost of $20 million. The final two acquisitions were completed in October 2017 for $20 million. The projects commenced commercial operations in November 2017 at a cost of $41 million, including the initial acquisition costs, and generate approximately 20 MW combined. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects described above. These projects are included in Power Generation. Dominion Energy has claimed or will claim federal investment tax credits on these solar projects.

Operating Revenue

Operating Revenue	6 Months Ended
	Jun. 30, 2018
Regulated And Unregulated Operating Revenue [Abstract]
Operating Revenue	Note 4. Operating Revenue The Companies’ operating revenue, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, consists of the following: Three Months Ended June 30, Six Months Ended June 30, 2018 2018 (millions) Dominion Energy Regulated electric sales: Residential $ 788 $ 1,605 Commercial 636 1,160 Industrial 121 228 Government and other retail 210 423 Wholesale 23 65 Nonregulated electric sales 282 700 Regulated gas sales: Residential 116 480 Commercial 34 137 Other 1 11 Nonregulated gas sales 9 97 Regulated gas transportation and storage: FERC-regulated 272 534 State-regulated 144 334 Nonregulated gas transportation and storage 124 124 Other regulated revenues 44 94 Other nonregulated revenues (1)(2) 141 277 Total operating revenue from contracts with customers 2,945 6,269 Other revenues 143 285 Total operating revenue $ 3,088 $ 6,554 Virginia Power Regulated electric sales: Residential $ 788 $ 1,605 Commercial 636 1,160 Industrial 121 228 Government and other retail 210 423 Wholesale 23 65 Other regulated revenues 33 65 Other nonregulated revenues (1) 18 31 Total operating revenue from contracts with customers $ 1,829 $ 3,577 Dominion Energy Gas Regulated gas sales: Residential $ 13 $ 42 Other 2 9 Nonregulated gas sales (1) 1 3 Regulated gas transportation and storage: FERC-regulated (1) 183 382 State-regulated (1) 139 319 NGL revenue (1)(2) 50 104 Management service revenue (1) 60 107 Other regulated revenues (1) 4 12 Other nonregulated revenues (1) 4 6 Total operating revenue from contracts with customers 456 984 Other revenues (1) 3 1 Total operating revenue $ 459 $ 985 (1) See Notes 10 and 18 for amounts attributable to related parties and affiliates. (2) Amounts above include $33 million and $21 million for the three months ended June 30, 2018, and $63 million and $47 million for the six months ended June 30, 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. 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 June 30, 2018 2018 2019 2020 2021 2022 Thereafter Total (millions) Dominion Energy $ 851 $ 1,686 $ 1,578 $ 1,466 $ 1,335 $ 15,240 $ 22,156 Virginia Power 11 21 3 1 — — 36 Dominion Energy Gas 324 633 570 485 394 2,168 4,574 Contract assets represent an entity’s right to consideration in exchange for goods and services that the entity has transferred to a customer. At both June 30, 2018 and December 31, 2017, Dominion Energy’s contract asset balances were $46 million. Dominion Energy Gas’ contract asset balances were $64 million and $66 million at June 30, 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 June 30, 2018 and December 31, 2017, Dominion Energy’s contract liability balances were $71 million and $132 million, respectively. At June 30, 2018 and December 31, 2017, Virginia Power’s contract liability balances were $25 million and $50 million, respectively. At June 30, 2018 and December 31, 2017, Dominion Energy Gas’ contract liability balances were $14 million and $41 million, respectively. During the six months ended June 30, 2018, Dominion Energy, Virginia Power and Dominion Energy Gas recognized revenue of $88 million, $21 million and $40 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: Three Months Ended June 30, Six Months Ended June 30, 2017 2017 (millions) Dominion Energy Electric sales: Regulated $ 1,716 $ 3,482 Nonregulated 307 734 Gas sales: Regulated 151 599 Nonregulated 110 254 Gas transportation and storage 430 922 Other 99 206 Total operating revenue $ 2,813 $ 6,197 Virginia Power Regulated electric sales $ 1,716 $ 3,482 Other 31 96 Total operating revenue $ 1,747 $ 3,578 Dominion Energy Gas Gas sales: Regulated $ 15 $ 47 Nonregulated 8 10 Gas transportation and storage 342 738 Other 57 117 Total operating revenue $ 422 $ 912

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Note 5. Income Taxes 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 Six Months Ended June 30, 2018 2017 2018 2017 2018 2017 U.S. statutory rate 21.0 % 35.0 % 21.0 % 35.0 % 21.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.8 2.8 4.5 3.7 3.6 1.5 Investment tax credits (0.9 ) (5.5 ) (1.4 ) (0.8 ) — — Production tax credits (0.7 ) (0.8 ) (0.7 ) (0.5 ) — — Reversal of excess deferred income taxes (1.5 ) — (2.0 ) — (1.2 ) — State legislative change (1.6 ) — — — 0.3 — AFUDC - equity (1.0 ) (1.4 ) (0.5 ) (0.6 ) (0.4 ) (1.0 ) Other, net (1.0 ) (2.6 ) 0.3 (0.1 ) 0.2 — Effective tax rate 18.1 % 27.5 % 21.2 % 36.7 % 23.5 % 35.5 % 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 being recorded at the new 21% rate. 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%. For the three and six months ended June 30, 2018, the Companies have recorded an estimate of the portion of excess deferred income tax amortization expected to occur in 2018. 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 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. Beginning in 2018, the 2017 Tax Reform Act limits the deductibility of interest expense to 30% of adjusted taxable income for certain businesses, with any disallowed interest carried forward indefinitely. Subject to additional guidance in yet to be issued regulations, the Companies expect interest expense to be deductible in 2018. The Companies continue to evaluate the changes in accelerated depreciation for income tax purposes and state conformity to the provisions of the 2017 Tax Reform Act. As of June 30, 2018, there have been no changes to the provisional amounts recorded at December 31, 2017. See Note 5 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, for a discussion of the impacts of the 2017 Tax Reform Act. As of June 30, 2018, there have been no material changes in the Companies’ unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 5 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, for a discussion of these unrecognized tax benefits.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share	Note 6. Earnings Per Share The following table presents the calculation of Dominion Energy’s basic and diluted EPS: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions, except EPS) Net income attributable to Dominion Energy $ 449 $ 390 $ 952 $ 1,022 Average shares of common stock outstanding – Basic 652.8 629.2 651.6 628.7 Net effect of dilutive securities 0.3 — 0.2 — Average shares of common stock outstanding – Diluted 653.1 629.2 651.8 628.7 Earnings Per Common Share – Basic $ 0.69 $ 0.62 $ 1.46 $ 1.63 Earnings Per Common Share – Diluted $ 0.69 $ 0.62 $ 1.46 $ 1.63 The 2014 Equity Units were potentially dilutive securities, but were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2017, as the diluted stock price threshold was not met. The 2016 Equity Units are potentially dilutive securities, but were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2018 and 2017, as the dilutive stock price threshold was not met. The Dominion Energy Midstream convertible preferred units are potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and six months ended June 30, 2018 and 2017 . In calculating diluted EPS in connection with the Dominion Energy Midstream convertible preferred units, Dominion Energy applies the if-converted method. The forward sales agreements, effective April 2018, are potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and six months ended June 30, 2018. See Note 15 for more information regarding the forward sales agreements. In calculating diluted EPS in connection with the forward sales agreements, Dominion Energy applies the treasury stock method.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Accumulated Other Comprehensive Income	Note 7. Accumulated Other Comprehensive Income Dominion Energy The following table presents Dominion Energy’s changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrealized gains and losses on investment securities Unrecognized pension and other postretirement benefit costs Other comprehensive loss from equity method investees Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (248 ) $ 3 $ (1,303 ) $ (3 ) $ (1,551 ) Other comprehensive income before reclassifications: gains (losses) (33 ) (5 ) — 1 (37 ) Amounts reclassified from AOCI: (gains) losses (1) 33 — 17 — 50 Net current period other comprehensive income (loss) — (5 ) 17 1 13 Ending balance $ (248 ) $ (2 ) $ (1,286 ) $ (2 ) $ (1,538 ) Three Months Ended June 30, 2017 Beginning balance $ (260 ) $ 599 $ (1,069 ) $ (5 ) $ (735 ) Other comprehensive income before reclassifications: gains (losses) 28 35 — 1 64 Amounts reclassified from AOCI: (gains) losses (1) (18 ) (4 ) 11 — (11 ) Net current period other comprehensive income (loss) 10 31 11 1 53 Ending balance $ (250 ) $ 630 $ (1,058 ) $ (4 ) $ (682 ) Six Months Ended June 30, 2018 Beginning balance $ (302 ) $ 747 $ (1,101 ) $ (3 ) $ (659 ) Other comprehensive income before reclassifications: gains (losses) 78 (18 ) — 1 61 Amounts reclassified from AOCI: (gains) losses (1) 41 1 42 — 84 Net current period other comprehensive income (loss) 119 (17 ) 42 1 145 Cumulative-effect of changes in accounting principle (64 ) (732 ) (227 ) — (1,023 ) Less other comprehensive income attributable to noncontrolling interest 1 — — — 1 Ending balance $ (248 ) $ (2 ) $ (1,286 ) $ (2 ) $ (1,538 ) Six Months Ended June 30, 2017 Beginning balance $ (280 ) $ 569 $ (1,082 ) $ (6 ) $ (799 ) Other comprehensive income before reclassifications: gains (losses) 71 93 — 2 166 Amounts reclassified from AOCI: (gains) losses (1) (41 ) (32 ) 24 — (49 ) Net current period other comprehensive income (loss) 30 61 24 2 117 Ending balance $ (250 ) $ 630 $ (1,058 ) $ (4 ) $ (682 ) (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 reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 16 Operating revenue Interest rate contracts 12 Interest and related charges Foreign currency contracts 16 Other income Total 44 Tax (11 ) Income tax expense Total, net of tax $ 33 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ 1 Other income Total 1 Tax (1 ) Income tax expense Total, net of tax $ — Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (5 ) Other income Amortization of actuarial losses 29 Other income Total 24 Tax (7 ) Income tax expense Total, net of tax $ 17 Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (19 ) Operating revenue (2 ) Electric fuel and other energy-related purchases Interest rate contracts 11 Interest and related charges Foreign currency contracts (19 ) Other income Total (29 ) Tax 11 Income tax expense Total, net of tax $ (18 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (11 ) Other income Impairment 5 Other income Total (6 ) Tax 2 Income tax expense Total, net of tax $ (4 ) Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (5 ) Other income Amortization of actuarial losses 26 Other income Total 21 Tax (10 ) Income tax expense Total, net of tax $ 11 Six Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 28 Operating revenue 2 Purchased gas (7 ) Electric fuel and other energy-related purchases Interest rate contracts 24 Interest and related charges Foreign currency contracts 8 Other income Total 55 Tax (14 ) Income tax expense Total, net of tax $ 41 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ 2 Other income Total 2 Tax (1 ) Income tax expense Total, net of tax $ 1 Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (11 ) Other income Amortization of actuarial losses 61 Other income Total 50 Tax (8 ) Income tax expense Total, net of tax $ 42 Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (81 ) Operating revenue (2 ) Electric fuel and other energy-related purchases Interest rate contracts 23 Interest and related charges Foreign currency contracts (6 ) Other income Total (66 ) Tax 25 Income tax expense Total, net of tax $ (41 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (64 ) Other income Impairment 14 Other income Total (50 ) Tax 18 Income tax expense Total, net of tax $ (32 ) Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (9 ) Other income Amortization of actuarial losses 51 Other income Total 42 Tax (18 ) Income tax expense Total, net of tax $ 24 Virginia Power The following table presents Virginia Power’s changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrealized gains and losses on investment securities Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (10 ) $ 1 $ (9 ) Other comprehensive income before reclassifications: gains (losses) 2 (2 ) — Amounts reclassified from AOCI: (gains) losses — — — Net current period other comprehensive income (loss) 2 (2 ) — Ending balance $ (8 ) $ (1 ) $ (9 ) Three Months Ended June 30, 2017 Beginning balance $ (8 ) $ 58 $ 50 Other comprehensive income before reclassifications: gains (losses) (3 ) 4 1 Amounts reclassified from AOCI: (gains) losses (1) 1 (1 ) — Net current period other comprehensive income (loss) (2 ) 3 1 Ending balance $ (10 ) $ 61 $ 51 Six Months Ended June 30, 2018 Beginning balance $ (12 ) $ 74 $ 62 Other comprehensive income before reclassifications: gains (losses) 7 (2 ) 5 Amounts reclassified from AOCI: (gains) losses — — — Net current period other comprehensive income (loss) 7 (2 ) 5 Cumulative-effect of changes in accounting principle (3 ) (73 ) (76 ) Ending balance $ (8 ) $ (1 ) $ (9 ) Six Months Ended June 30, 2017 Beginning balance $ (8 ) $ 54 $ 46 Other comprehensive income before reclassifications: gains (losses) (3 ) 11 8 Amounts reclassified from AOCI: (gains) losses (1) 1 (4 ) (3 ) Net current period other comprehensive income (loss) (2 ) 7 5 Ending balance $ (10 ) $ 61 $ 51 (1) See table below for details about these reclassifications. The following table presents Virginia Power’s reclassifications out of AOCI by component. Reclassifications out of AOCI were immaterial for the three and six months ended June 30, 2018. Details about AOCI components Amounts reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: 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 $ (1 ) Other income Total (1 ) Tax — Income tax expense Total, net of tax $ (1 ) Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: 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 $ (7 ) Other income Impairment 1 Other income Total (6 ) Tax 2 Income tax expense Total, net of tax $ (4 ) Dominion Energy Gas The following table presents Dominion Energy Gas’ changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrecognized pension costs Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (18 ) $ (95 ) $ (113 ) Other comprehensive income before reclassifications: gains (losses) (20 ) — (20 ) Amounts reclassified from AOCI: (gains) losses (1) 14 1 15 Net current period other comprehensive income (loss) (6 ) 1 (5 ) Ending balance $ (24 ) $ (94 ) $ (118 ) Three Months Ended June 30, 2017 Beginning balance $ (22 ) $ (99 ) $ (121 ) Other comprehensive income before reclassifications: gains (losses) 11 — 11 Amounts reclassified from AOCI: (gains) losses (1) (12 ) 2 (10 ) Net current period other comprehensive income (loss) (1 ) 2 1 Ending balance $ (23 ) $ (97 ) $ (120 ) Six Months Ended June 30, 2018 Beginning balance $ (23 ) $ (75 ) $ (98 ) Other comprehensive income before reclassifications: gains (losses) (7 ) — (7 ) Amounts reclassified from AOCI: (gains) losses (1) 11 2 13 Net current period other comprehensive income (loss) 4 2 6 Cumulative-effect of changes in accounting principle (5 ) (21 ) (26 ) Ending balance $ (24 ) $ (94 ) $ (118 ) Six Months Ended June 30, 2017 Beginning balance $ (24 ) $ (99 ) $ (123 ) Other comprehensive income before reclassifications: gains (losses) 2 — 2 Amounts reclassified from AOCI: (gains) losses (1) (1 ) 2 1 Net current period other comprehensive income (loss) 1 2 3 Ending balance $ (23 ) $ (97 ) $ (120 ) (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 reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 2 Operating revenue Interest rate contracts 1 Interest and related charges Foreign currency contracts 16 Other income Total 19 Tax (5 ) Income tax expense Total, net of tax $ 14 Unrecognized pension costs: Actuarial losses $ 1 Other income Total 1 Tax — Income tax expense Total, net of tax $ 1 Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (1 ) Operating revenue Interest rate contracts 1 Interest and related charges Foreign currency contracts (19 ) Other income Total (19 ) Tax 7 Income tax expense Total, net of tax $ (12 ) Unrecognized pension costs: Actuarial losses $ 2 Other income Total 2 Tax — Income tax expense Total, net of tax $ 2 Six Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 5 Operating revenue Interest rate contracts 2 Interest and related charges Foreign currency contracts 8 Other income Total 15 Tax (4 ) Income tax expense Total, net of tax $ 11 Unrecognized pension costs: Actuarial losses $ 3 Other income Total 3 Tax (1 ) Income tax expense Total, net of tax $ 2 Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 3 Operating revenue Interest rate contracts 2 Interest and related charges Foreign currency contracts (6 ) Other income Total (1 ) Tax — Income tax expense Total, net of tax $ (1 ) Unrecognized pension costs: Actuarial losses $ 3 Other income Total 3 Tax (1 ) Income tax expense Total, net of tax $ 2

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2018
Dominion Energy Gas Holdings, LLC
Fair Value Measurements	Note 8. Fair Value Measurements The Companies’ fair value measurements are made in accordance with the policies discussed in Note 6 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. See Note 9 in this report for further information about the Companies’ derivatives and hedge accounting activities. 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, futures, and swaps contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards, futures, and swaps calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices, and volumes. For Level 3 fair value measurements, certain forward market prices and implied price volatilities are considered unobservable. The unobservable inputs are developed and substantiated using historical information, available market data, third-party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third-party pricing sources. The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at June 30, 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 Average (1) Assets Physical and financial forwards and futures: Natural gas (2) $ 90 Discounted cash flow Market price (per Dth) (3) (1) - 6 — FTRs 7 Discounted cash flow Market price (per MWh) (3) (1) - 6 — Physical options: Natural gas 1 Option model Market price (per Dth) (3) 2 - 6 3 Price volatility (4) 13% - 35% 23 % Electricity 24 Option model Market price (per MWh) (3) 24 - 51 37 Price volatility (4) 4% - 62% 29 % Total assets $ 122 Liabilities Financial forwards: FTRs $ 3 Discounted cash flow Market price (per MWh) (3) (1) - 6 1 Total liabilities $ 3 (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 Value Measurement Market price Buy Increase (decrease) Gain (loss) Market price Sell Increase (decrease) Loss (gain) Price volatility Buy Increase (decrease) Gain (loss) Price volatility Sell Increase (decrease) Loss (gain) Recurring Fair Value Measurements Dominion Energy 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) At June 30, 2018 Assets Derivatives: Commodity $ — $ 37 $ 122 $ 159 Interest rate — 58 — 58 Foreign currency — 33 — 33 Investments (1) Equity securities: U.S. 3,529 — — 3,529 Fixed income securities: Corporate debt instruments — 445 — 445 Government securities 270 837 — 1,107 Cash equivalents and other 14 — — 14 Total assets $ 3,813 $ 1,410 $ 122 $ 5,345 Liabilities Derivatives: Commodity $ — $ 52 $ 3 $ 55 Interest rate — 58 — 58 Foreign currency — 5 — 5 Total liabilities $ — $ 115 $ 3 $ 118 At 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 securities: 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 $211 million and $88 million of assets at June 30, 2018 and December 31, 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: Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Beginning balance $ 120 $ 130 $ 150 $ 139 Total realized and unrealized gains (losses): Included in earnings (2 ) (10 ) (20 ) (25 ) Included in other comprehensive income — — 1 — Included in regulatory assets/liabilities 11 32 (10 ) 23 Settlements (10 ) — (3 ) 12 Transfers out of Level 3 — — 1 3 Ending balance $ 119 $ 152 $ 119 $ 152 The following table presents Dominion Energy’s classification of gains and losses included in earnings in the Level 3 fair value category. The unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date were not material for the three and six months ended June 30, 2018 and 2017. Operating Revenue Electric Fuel and Other Energy-Related Purchases Total (millions) Three Months Ended June 30, 2018 Total gains (losses) included in earnings $ — $ (2 ) $ (2 ) Three Months Ended June 30, 2017 Total gains (losses) included in earnings $ — $ (10 ) $ (10 ) Six Months Ended June 30, 2018 Total gains (losses) included in earnings $ (1 ) $ (19 ) $ (20 ) Six Months Ended June 30, 2017 Total gains (losses) included in earnings $ — $ (25 ) $ (25 ) Virginia Power The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at June 30, 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 Average (1) Assets Physical and financial forwards and futures: Natural gas (2) $ 86 Discounted cash flow Market price (per Dth) (3) (1) - 6 (1 ) FTRs 7 Discounted cash flow Market price (per MWh) (3) (1) - 6 — Physical options: Natural gas 1 Option model Market price (per Dth) (3) 2 - 6 3 Price volatility (4) 13% - 35% 23 % Electricity 24 Option model Market price (per MWh) (3) 24 - 51 37 Price volatility (4) 4% - 62% 29 % Total assets $ 118 Liabilities Financial forwards: FTRs $ 3 Discounted cash flow Market price (per MWh) (3) (1) - 6 1 Total liabilities $ 3 (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 Value Measurement Market price Buy Increase (decrease) Gain (loss) Market price Sell Increase (decrease) Loss (gain) Price volatility Buy Increase (decrease) Gain (loss) Price volatility Sell Increase (decrease) Loss (gain) The following table presents Virginia Power’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions: Level 1 Level 2 Level 3 Total (millions) At June 30, 2018 Assets Derivatives: Commodity $ — $ 8 $ 118 $ 126 Interest rate — 21 — 21 Investments (1) Equity securities: U.S. 1,584 — — 1,584 Fixed income securities: Corporate debt instruments — 227 — 227 Government securities 164 328 — 492 Cash equivalents and other 3 — — 3 Total assets $ 1,751 $ 584 $ 118 $ 2,453 Liabilities Derivatives: Commodity $ — $ 5 $ 3 $ 8 Interest rate — 6 — 6 Total liabilities $ — $ 11 $ 3 $ 14 At December 31, 2017 Assets Derivatives: Commodity $ — $ 14 $ 152 $ 166 Investments (1) Equity securities: U.S. 1,566 — — 1,566 Fixed income securities: 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 $171 million and $27 million of assets at June 30, 2018 and December 31, 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: Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Beginning balance $ 117 $ 132 $ 147 $ 143 Total realized and unrealized gains (losses): Included in earnings (2 ) (10 ) (19 ) (25 ) Included in regulatory assets/liabilities 8 31 (11 ) 23 Settlements (8 ) (1 ) (2 ) 11 Ending balance $ 115 $ 152 $ 115 $ 152 The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income for the three and six months ended June 30, 2018 and 2017. There were no unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and six months ended June 30, 2018 and 2017. Dominion Energy Gas 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) At June 30, 2018 Assets Interest rate $ — $ 1 $ — $ 1 Foreign currency — 33 — 33 Total assets $ — $ 34 $ — $ 34 Liabilities Commodity $ — $ 7 $ — $ 7 Interest rate — 4 — 4 Foreign currency — 5 — 5 Total liabilities $ — $ 16 $ — $ 16 At 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’ assets and liabilities for derivatives measured at fair value on a recurring basis and included in the Level 3 fair value category. There were no net changes in assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category for the three months ended June 30, 2018 and 2017. Six Months Ended June 30, 2018 2017 (millions) Beginning balance $ (2 ) $ (2 ) Total realized and unrealized gains (losses): Included in other comprehensive income (loss) 1 (1 ) Transfers out of Level 3 1 3 Ending balance $ — $ — There were no gains or losses included in earnings in the Level 3 fair value category for the six months ended June 30, 2018 and 2017. There were no unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the six months ended June 30, 2018 and 2017. Fair Value of Financial Instruments Substantially all of the Companies’ financial instruments are recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of cash and cash equivalents, restricted cash 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: June 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Energy Long-term debt, including securities due within one year (2) $ 29,629 $ 30,779 $ 28,666 $ 31,233 Junior subordinated notes (3) 3,981 4,016 3,981 4,102 Remarketable subordinated notes (3) 1,382 1,294 1,379 1,446 Credit facility borrowings 73 73 — — Virginia Power Long-term debt, including securities due within one year (3) $ 11,091 $ 11,799 $ 11,346 $ 12,842 Dominion Energy Gas Long-term debt, including securities due within one year (4) $ 4,062 $ 4,094 $ 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 issues with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value. (2) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At June 30, 2018 and December 31, 2017, includes the valuation of certain fair value hedges associated with fixed rate debt of $(61) 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	6 Months Ended
	Jun. 30, 2018
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivatives and Hedge Accounting Activities	Note 9. Derivatives and Hedge Accounting Activities The Companies’ accounting policies, objectives and strategies for using derivative instruments are discussed in Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. See Note 8 in this report for further information about fair value measurements and associated valuation methods for derivatives. Derivative assets and liabilities are presented gross on the Companies’ Consolidated Balance Sheets. Dominion Energy’s derivative contracts include both over-the-counter transactions and those that are executed on an exchange or other trading platform (exchange contracts) and centrally cleared. Virginia Power and Dominion Energy Gas’ derivative contracts include over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute, or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements, and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency, or other conditions. In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities. Certain accounts receivable and accounts payable recognized on the Companies’ Consolidated Balance Sheets, as well as letters of credit and other forms of security, all of which are not included in the tables below, are subject to offset under master netting or similar arrangements and would reduce the net exposure. See Note 17 for further information regarding credit-related contingent features for the Companies’ derivative instruments. Dominion Energy Balance Sheet Presentation The tables below present Dominion Energy’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting: June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 130 $ — $ 130 $ 174 $ — $ 174 Exchange 21 — 21 80 — 80 Interest rate contracts: Over-the-counter 58 — 58 17 — 17 Foreign currency contracts: Over-the-counter 33 — 33 32 — 32 Total derivatives, subject to a master netting or similar arrangement 242 — 242 303 — 303 Total derivatives, not subject to a master netting or similar arrangement 8 — 8 4 — 4 Total $ 250 $ — $ 250 $ 307 $ — $ 307 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 130 $ 7 $ — $ 123 $ 174 $ 9 $ — $ 165 Exchange 21 21 — — 80 80 — — Interest rate contracts: Over-the-counter 58 9 — 49 17 8 — 9 Foreign currency contracts: Over-the-counter 33 5 — 28 32 2 — 30 Total $ 242 $ 42 $ — $ 200 $ 303 $ 99 $ — $ 204 June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 23 $ — $ 23 $ 76 $ — $ 76 Exchange 32 — 32 120 — 120 Interest rate contracts: Over-the-counter 58 — 58 85 — 85 Foreign currency contracts: Over-the-counter 5 — 5 2 — 2 Total derivatives, subject to a master netting or similar arrangement 118 — 118 283 — 283 Total derivatives, not subject to a master netting or similar arrangement — — — 1 — 1 Total $ 118 $ — $ 118 $ 284 $ — $ 284 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 23 $ 7 $ — $ 16 $ 76 $ 9 $ 6 $ 61 Exchange 32 21 11 — 120 80 40 — Interest rate contracts: Over-the-counter 58 9 — 49 85 8 — 77 Foreign currency contracts: Over-the-counter 5 5 — — 2 2 — — Total $ 118 $ 42 $ 11 $ 65 $ 283 $ 99 $ 46 $ 138 Volumes The following table presents the volume of Dominion Energy’s derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 75 24 Basis 214 600 Electricity (MWh): Fixed price (1) 10,566,074 677,760 FTRs 102,797,191 — Liquids (Gal) (2) 51,019,800 — Interest rate (3) $ 600,000,000 $ 5,433,632,652 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 three and six months ended June 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness were not material. Amounts excluded from the assessment of effectiveness include 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 June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Commodities: Gas $ — $ 1 37 months Electricity (9 ) (9 ) 18 months Other (5 ) (5 ) 9 months Interest rate (246 ) (9 ) 378 months Foreign currency 12 (4 ) 96 months Total $ (248 ) $ (26 ) 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’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Current Assets Commodity $ 10 $ 67 $ 77 Interest rate 12 — 12 Total current derivative assets (1) 22 67 89 Noncurrent Assets Commodity 1 81 82 Interest rate 46 — 46 Foreign currency 33 — 33 Total noncurrent derivative assets (2) 80 81 161 Total derivative assets $ 102 $ 148 $ 250 LIABILITIES Current Liabilities Commodity $ 30 $ 22 $ 52 Interest rate 12 — 12 Foreign currency 5 — 5 Total current derivative liabilities (3) 47 22 69 Noncurrent Liabilities Commodity 2 1 3 Interest rate 46 — 46 Total noncurrent derivative liabilities (4) 48 1 49 Total derivative liabilities $ 95 $ 23 $ 118 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 in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Three Months Ended June 30, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (16 ) Total commodity $ (39 ) $ (16 ) $ — Interest rate (3) 9 (12 ) 25 Foreign currency (4) (14 ) (16 ) — Total $ (44 ) $ (44 ) $ 25 Three Months Ended June 30, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 19 Electric fuel and other energy-related purchases 2 Total commodity $ 44 $ 21 $ — Interest rate (3) (15 ) (11 ) (42 ) Foreign currency (4) 16 19 — Total $ 45 $ 29 $ (42 ) Six Months Ended June 30, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (28 ) Purchased gas (2 ) Electric fuel and other energy-related purchases 7 Total commodity $ 58 $ (23 ) $ — Interest rate (3) 47 (24 ) 93 Foreign currency (4) (1 ) (8 ) — Total $ 104 $ (55 ) $ 93 Six Months Ended June 30, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 81 Electric fuel and other energy-related purchases 2 Total commodity $ 131 $ 83 $ — Interest rate (3) (14 ) (23 ) (34 ) Foreign currency (4) (2 ) 6 — Total $ 115 $ 66 $ (34 ) (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 Income on Derivatives (1) Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (9 ) $ 10 $ (3 ) $ 14 Purchased gas 4 (8 ) 4 8 Electric fuel and other energy-related purchases (3 ) (8 ) (16 ) (32 ) Other operations & maintenance — (1 ) — (1 ) Total $ (8 ) $ (7 ) $ (15 ) $ (11 ) (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 Power Balance Sheet Presentation The tables below present Virginia Power’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting: June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 117 $ — $ 117 $ 155 $ — $ 155 Interest rate contracts: Over-the-counter 21 — 21 — — — Total derivatives, subject to a master netting or similar arrangement 138 — 138 155 — 155 Total derivatives, not subject to a master netting or similar arrangement 9 — 9 11 — 11 Total $ 147 $ — $ 147 $ 166 $ — $ 166 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 117 $ 3 $ — $ 114 $ 155 $ 4 $ — $ 151 Interest rate contracts: Over-the-counter 21 3 — 18 — — — — Total $ 138 $ 6 $ — $ 132 $ 155 $ 4 $ — $ 151 June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 3 $ — $ 3 $ 4 $ — $ 4 Interest rate contracts: Over-the-counter 6 — 6 57 — 57 Total derivatives, subject to a master netting or similar arrangement 9 — 9 61 — 61 Total derivatives, not subject to a master netting or similar arrangement 5 — 5 5 — 5 Total $ 14 $ — $ 14 $ 66 $ — $ 66 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 3 $ 3 $ — $ — $ 4 $ 4 $ — $ — Interest rate contracts: Over-the-counter 6 3 — 3 57 — — 57 Total $ 9 $ 6 $ — $ 3 $ 61 $ 4 $ — $ 57 Volumes The following table presents the volume of Virginia Power’s derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 27 4 Basis 112 514 Electricity (MWh): Fixed price (1) 1,061,191 — FTRs 101,284,984 — Interest rate (2) $ 600,000,000 $ 1,000,000,000 (1) Includes options. (2) Maturity is determined based on final settlement period. Ineffectiveness and AOCI For the three and six months ended June 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective were not material. The following table presents selected information related to losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (8 ) $ (1 ) 378 months Total $ (8 ) $ (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 table presents the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Current Assets Commodity $ — $ 49 $ 49 Interest rate 8 — 8 Total current derivative assets (1) 8 49 57 Noncurrent Assets Commodity — 77 77 Interest rate 13 — 13 Total noncurrent derivative assets (2) 13 77 90 Total derivative assets $ 21 $ 126 $ 147 LIABILITIES Current Liabilities Commodity $ — $ 8 $ 8 Interest rate 4 — 4 Total current derivative liabilities (3) 4 8 12 Noncurrent Liabilities Interest rate 2 — 2 Total noncurrent derivatives liabilities (4) 2 — 2 Total derivative liabilities $ 6 $ 8 $ 14 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 derivatives 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Three Months Ended June 30, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 2 $ — $ 25 Total $ 2 $ — $ 25 Three Months Ended June 30, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (5 ) $ (1 ) $ (42 ) Total $ (5 ) $ (1 ) $ (42 ) Six Months Ended June 30, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 9 $ — $ 93 Total $ 9 $ — $ 93 Six Months Ended June 30, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (5 ) $ (1 ) $ (34 ) Total $ (5 ) $ (1 ) $ (34 ) (1) Amounts deferred into AOCI have no associated effect in Virginia Power’s Consolidated Statements of Income. (2) Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power’s Consolidated Statements of Income. (3) Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in Income on Derivatives (1) Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Derivative type and location of gains (losses): Commodity (2) $ (3 ) $ (7 ) $ (3 ) $ (24 ) Total $ (3 ) $ (7 ) $ (3 ) $ (24 ) (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 Balance Sheet Presentation The tables below present Dominion Energy Gas’ derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting. June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Interest rate contracts: Over-the-counter $ 1 $ — $ 1 $ — $ — $ — Foreign currency contracts: Over-the-counter 33 — 33 32 — 32 Total derivatives, subject to a master netting or similar arrangement $ 34 $ — $ 34 $ 32 $ — $ 32 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Interest rate contracts: Over-the-counter $ 1 $ 1 $ — $ — $ — $ — $ — $ — Foreign currency contracts: Over-the-counter 33 5 — 28 32 2 — 30 Total $ 34 $ 6 $ — $ 28 $ 32 $ 2 $ — $ 30 June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 7 $ — $ 7 $ 6 $ — $ 6 Interest rate contracts: Over-the-counter 4 — 4 — — — Foreign currency contracts: Over-the-counter 5 — 5 2 — 2 Total derivatives, subject to a master netting or similar arrangement $ 16 $ — $ 16 $ 8 $ — $ 8 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts Over-the-counter $ 7 $ — $ — $ 7 $ 6 $ — $ — $ 6 Interest rate contracts: Over-the-counter 4 1 — 3 — — — — Foreign currency contracts: Over-the-counter 5 5 — — 2 2 — — Total $ 16 $ 6 $ — $ 10 $ 8 $ 2 $ — $ 6 Volumes The following table presents the volume of Dominion Energy Gas’ derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Basis 1 — NGLs (Gal) 45,643,800 — Interest rate (1) $ — $ 1,050,000,000 Foreign currency (1)(2) $ — $ 280,000,000 (1) Maturity is based on final settlement period. (2) Euro equivalent volumes are €250,000,000. Ineffectiveness and AOCI For the three and six months ended June 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective were not material. The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy Gas’ Consolidated Balance Sheet at June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Commodities: NGLs $ (5 ) $ (5 ) 9 months Interest rate (31 ) (4 ) 318 months Foreign currency 12 (4 ) 96 months Total $ (24 ) $ (13 ) 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 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 Gas’ derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value-Derivatives Under Hedge Accounting Fair Value-Derivatives Not Under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Noncurrent Assets Interest rate $ 1 $ — $ 1 Foreign currency 33 — 33 Total noncurrent derivative assets (1) 34 — 34 Total derivative assets $ 34 $ — $ 34 LIABILITIES Current Liabilities Commodity $ 7 $ — $ 7 Interest rate 1 — 1 Foreign currency 5 — 5 Total current derivative liabilities (2) 13 — 13 Noncurrent Liabilities Interest rate 3 — 3 Total noncurrent derivative liabilities (3) 3 — 3 Total derivative liabilities $ 16 $ — $ 16 December 31, 2017 ASSETS Noncurrent Assets Foreign currency $ 32 $ — $ 32 Total noncurrent derivative assets (1) 32 — 32 Total derivative assets $ 32 $ — $ 32 LIABILITIES Current Liabilities Commodity $ 6 $ — $ 6 Foreign currency 2 — 2 Total current derivative liabilities (2) 8 — 8 Total derivative liabilities $ 8 $ — $ 8 (1) Noncurrent derivatives assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (2) Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (3) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. The following table presents 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income (millions) Three Months Ended June 30, 2018 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (2 ) Total commodity $ (10 ) $ (2 ) Interest rate (2) (3 ) (1 ) Foreign currency (3) (14 ) (16 ) Total $ (27 ) $ (19 ) Three Months Ended June 30, 2017 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ 1 Total commodity $ 2 $ 1 Interest rate (2) — (1 ) Foreign currency (3) 16 19 Total $ 18 $ 19 Six Months Ended June 30, 2018 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (5 ) Total commodity $ (6 ) $ (5 ) Interest rate (2) (3 ) (2 ) Foreign currency (3) (1 ) (8 ) Total $ (10 ) $ (15 ) Six Months Ended June 30, 2017 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (3 ) Total commodity $ 4 $ (3 ) Interest rate (2) — (2 ) Foreign currency (3) (1 ) 6 Total $ 3 $ 1 (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.

Investments

Investments	6 Months Ended
	Jun. 30, 2018
Investments Debt And Equity Securities [Abstract]
Investments	Note 10. Investments Dominion Energy Equity and Debt Securities Rabbi Trust Securities Equity and debt securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled $114 Decommissioning Trust Securities 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 Value (millions) June 30, 2018 Equity securities: (1) U.S. $ 1,695 $ 1,896 $ (14 ) $ 3,577 Fixed income securities: (2) Corporate debt instruments 447 6 (8 ) 445 Government securities 1,058 16 (14 ) 1,060 Common/collective trust funds 72 — — 72 Cash equivalents and other (3) 5 — — 5 Total $ 3,277 $ 1,918 $ (36 ) (4) $ 5,159 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 purchases of securities of $3 million at June 30, 2018 and pending sales of securities of (4) The fair value of securities in an unrealized loss position was $900 million The portion of unrealized gains and losses that relates to equity securities held within Dominion Energy’s nuclear decommissioning trusts is summarized below: (millions) Three Months Ended June 30, 2018 Six Months Ended June 30, 2018 Net gains recognized during the period $ 89 $ 24 Less: Net gains recognized during the period on securities sold during the period (16 ) (35 ) Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018 (1) $ 73 $ (11 ) (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 June 30, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 321 Due after one year through five years 327 Due after five years through ten years 353 Due after ten years 576 Total $ 1,577 Presented below is selected information regarding Dominion Energy’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Proceeds from sales $ 425 $ 363 $ 844 $ 1,119 Realized gains (1) 36 23 72 117 Realized losses (1) 23 16 42 36 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability. Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds recognized in earnings for Dominion Energy were not material for the three and six months ended June 30, 2018 and 2017. Virginia Power 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) June 30, 2018 Equity securities: (1) U.S. $ 837 $ 861 $ (7 ) $ 1,691 Fixed income securities: (2) Corporate debt instruments 228 3 (4 ) 227 Government securities 490 7 (5 ) 492 Common/collective trust funds 32 — — 32 Cash equivalents and other (3) 7 — — 7 Total $ 1,594 $ 871 $ (16 ) (4) $ 2,449 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 $5 million and (4) The fair value of securities in an unrealized loss position was $414 million The portion of unrealized gains and losses that relates to equity securities held within Virginia Power’s nuclear decommissioning trusts is summarized below: Three Months Ended June 30, 2018 Six Months Ended June 30, 2018 (millions) Net gains recognized during the period $ 44 $ 12 Less: Net gains recognized during the period on securities sold during the period (8 ) (23 ) Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018 (1) $ 36 $ (11 ) (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 June 30, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 49 Due after one year through five years 158 Due after five years through ten years 216 Due after ten years 328 Total $ 751 Presented below is selected information regarding Virginia Power’s equity and debt securities with readily determinable fair values held in nuclear decommissioning trust funds. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Proceeds from sales $ 196 $ 168 $ 414 $ 498 Realized gains (1) 15 10 33 55 Realized losses (1) 7 8 12 18 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability. Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds recognized in earnings for Virginia Power were not material for the three and six months ended June 30, 2018 and 2017. Equity Method Investments Dominion Energy Atlantic Coast Pipeline Dominion Energy recorded contributions of $81 million and $85 million during the three months ended June 30, 2018 and 2017, respectively, and $159 million and $202 million during the six months ended June 30, 2018 and 2017, respectively, to Atlantic Coast Pipeline. At June 30, 2018, Dominion Energy had $33 million of contributions payable to Atlantic Coast Pipeline included within other current liabilities in the Consolidated Balance Sheets. DETI provides services to Atlantic Coast Pipeline which totaled $60 million and $30 million for the three months ended June 30, 2018 and 2017, respectively, and $106 million and $61 million for the six months ended June 30, 2018 and 2017, respectively, included in operating revenue in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income. Amounts receivable related to these services were $19 million and $12 million at June 30, 2018 and December 31, 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 16 for more information. NedPower Dominion Energy has a liability of $1 million and $17 million recorded to other deferred credits and other liabilities on the Consolidated Balance Sheets at June 30, 2018 and December 31, 2017, respectively, relating to its commitment to provide further financial support for NedPower. Other In July 2018, Dominion Energy entered into an agreement to sell its 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership, which is accounted for as an equity method investment with zero carrying value at June 30, 2018. The transaction is expected to close in the third quarter of 2018 with proceeds of approximately $90 million, subject to customary closing adjustments. As a result, Dominion Energy expects to recognize a gain of approximately $90 million ($65 million after-tax) in the third quarter of 2018. Dominion Energy Gas Iroquois Dominion Energy Gas’ equity earnings totaled $14 million and $11 million for the six months ended June 30, 2018 and 2017, respectively. Dominion Energy Gas received distributions of $14 million and $11 million for the six months ended June 30, 2018 and 2017, respectively. At both June 30, 2018 and December 31, 2017, the carrying amount of Dominion Energy Gas’ investment of $95 million exceeded its share of underlying equity in net assets by $8 million. The difference reflects equity method goodwill and is not being amortized.

Property Plant and Equipment

Property Plant and Equipment	6 Months Ended
	Jun. 30, 2018
Property Plant And Equipment [Abstract]
Property Plant and Equipment	Note 11. Property, Plant and Equipment Virginia Power Assignment of Tower Rental Portfolio Virginia Power rents space on certain of its electric transmission towers to various wireless carriers for communications antennae 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 $1 million in operating revenue and $1 million in other income for the three months ended June 30, 2018 and 2017, respectively, and recorded $3 million in operating revenue and $8 million in other income for the six months ended June 30, 2018 and 2017, respectively, with $32 million remaining to be recognized ratably through 2023. Dominion Energy Gas Assignment of Shale Development Rights 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. In January 2018, Dominion Energy Gas and the natural gas producer closed on an amendment to the agreement, which included the conveyance of Dominion Energy Gas’ remaining 50% interest in approximately 18,000 acres and the elimination of Dominion Energy Gas’ overriding royalty interest in gas produced from all acreage. In February 2018, Dominion Energy Gas received proceeds of $28 million, resulting in an approximately $28 million ($20 million after-tax) gain recorded in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income. 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) gain recorded in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income. 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) gain recorded in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	6 Months Ended
	Jun. 30, 2018
Regulatory Assets And Liabilities Disclosure [Abstract]
Regulatory Assets and Liabilities	Note 12. Regulatory Assets and Liabilities Regulatory assets and liabilities include the following: June 30, 2018 December 31, 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred rate adjustment clause costs (2) 89 70 Deferred nuclear refueling outage costs (3) 76 54 Unrecovered gas costs (4) 3 38 Other 104 109 Regulatory assets-current 616 294 Unrecognized pension and other postretirement benefit costs (5) 1,296 1,336 Deferred rate adjustment clause costs (2) 372 401 PJM transmission rates (6) 237 222 Utility reform legislation (7) 174 147 Derivatives (8) 131 223 Other 185 151 Regulatory assets-noncurrent 2,395 2,480 Total regulatory assets $ 3,011 $ 2,774 Regulatory liabilities: Reserve for rate credits to electric utility customers (9) $ 200 $ — Provision for future cost of removal and AROs (10) 101 101 Other 123 92 Regulatory liabilities-current (11) 424 193 Income taxes refundable through future rates (12) 4,037 4,058 Provision for future cost of removal and AROs (10) 1,407 1,384 Nuclear decommissioning trust (13) 1,147 1,121 Cost-of-service impact of 2017 Tax Reform Act (14) 84 — Other 390 353 Regulatory liabilities-noncurrent 7,065 6,916 Total regulatory liabilities $ 7,489 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred nuclear refueling outage costs (3) 76 54 Deferred rate adjustment clause costs (2) 56 56 Other 76 72 Regulatory assets-current 552 205 Deferred rate adjustment clause costs (2) 296 312 PJM transmission rates (6) 237 222 Derivatives (8) 98 190 Other 98 86 Regulatory assets-noncurrent 729 810 Total regulatory assets $ 1,281 $ 1,015 Regulatory liabilities: Reserve for rate credits to customers (9) $ 200 $ — Provision for future cost of removal (10) 80 80 Other 25 47 Regulatory liabilities-current (11) 305 127 Income taxes refundable through future rates (12) 2,567 2,581 Nuclear decommissioning trust (13) 1,147 1,121 Provision for future cost of removal (10) 927 915 Cost-of-service impact of 2017 Tax Reform Act (14) 72 — Derivatives (8) 65 69 Other 99 74 Regulatory liabilities-noncurrent 4,877 4,760 Total regulatory liabilities $ 5,182 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 33 $ 14 Unrecovered gas costs (4) — 8 Other 2 4 Regulatory assets-current (15) 35 26 Unrecognized pension and other postretirement benefit costs (5) 251 258 Utility reform legislation (7) 174 147 Deferred rate adjustment clause costs (2) 76 89 Other 25 17 Regulatory assets-noncurrent (16) 526 511 Total regulatory assets $ 561 $ 537 Regulatory liabilities: Overrecovered gas costs (4) $ 18 $ — Provision for future cost of removal and AROs (10) 13 13 PIPP (17) 3 20 Other 14 5 Regulatory liabilities-current (11) 48 38 Income taxes refundable through future rates (12) 993 998 Provision for future cost of removal and AROs (10) 165 160 Cost-of-service impact of 2017 Tax Reform Act (14) 11 — Other 84 69 Regulatory liabilities-noncurrent 1,253 1,227 Total regulatory liabilities $ 1,301 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. (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 or refunded through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy's and Dominion Energy Gas' rate-regulated subsidiaries. (6) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) 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) 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. (10) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (11) Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets. (12) Amounts recorded to pass the effect of reduced income taxes 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. (13) 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. (14) 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. (15) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. (16) Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (17) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rate adjustment clause according to East Ohio tariff provisions. At June 30, 2018, $427 million of Dominion Energy's and $349 million of Virginia Power's regulatory assets represented past expenditures on which they do not currently earn a return. With the exception of the $237 million PJM transmission cost allocation matter, the majority of these expenditures are expected to be recovered within the next two years.

Regulatory Matters

Regulatory Matters	6 Months Ended
	Jun. 30, 2018
Regulated Operations [Abstract]
Regulatory Matters	Note 13. Regulatory Matters Regulatory Matters Involving Potential Loss Contingencies As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations. FERC - Electric Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Dominion Energy’s merchant generators sell electricity in the PJM, CAISO and ISO-NE wholesale markets, and to wholesale purchasers in the states of Virginia, North Carolina, Indiana, Connecticut, Tennessee, Georgia, California, South Carolina and Utah, under Dominion Energy’s market-based sales tariffs authorized by FERC or pursuant to FERC authority to sell as a qualified facility. Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power’s service territory. Any such sales would be voluntary. Rates In April 2008, FERC granted an application for Virginia Power’s electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure. In March 2010, Old Dominion Electric Cooperative 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 wholesale transmission customers to be allocated the incremental costs of undergrounding the facilities because the projects are a direct result of Virginia legislation and Virginia Commission pilot programs intended to benefit the citizens of Virginia. The order is retroactively effective as of March 2010 and will cause the reallocation of the costs charged to wholesale transmission customers with loads outside Virginia to wholesale transmission customers with loads in Virginia. FERC determined that there was not sufficient evidence on the record to determine the magnitude of the underground increment and held a hearing to determine the appropriate amount of undergrounding cost to be allocated to each wholesale transmission customer in Virginia. 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. While Virginia Power cannot predict the outcome of the matter, it is not expected to have a material effect on results of operations. PJM Transmission Rates In April 2007, FERC issued an order regarding its transmission rate design for the allocation of costs among PJM transmission customers, including Virginia Power, for transmission service provided by PJM. For new PJM-planned transmission facilities that operate at or above 500 kV, FERC established a PJM regional rate design where customers pay according to each customer’s share of the region’s load. For recovery of costs of existing facilities, FERC approved the existing methodology whereby a customer pays the cost of facilities located in the same zone as the customer. A number of parties appealed the order to the U.S. Court of Appeals for the Seventh Circuit. In August 2009, the court issued its decision affirming the FERC order with regard to the existing facilities, but remanded to FERC the issue of the cost allocation associated with the new facilities 500 kV and above for further consideration by FERC. On remand, FERC reaffirmed its earlier decision to allocate the costs of new facilities 500 kV and above according to the customer’s share of the region’s load. A number of parties filed appeals of the order to the U.S. Court of Appeals for the Seventh Circuit. In June 2014, the court again remanded the cost allocation issue to FERC. In December 2014, FERC issued an order setting an evidentiary hearing and settlement proceeding regarding the cost allocation issue. The hearing only concerns the costs of new facilities approved by PJM prior to February 1, 2013. Transmission facilities approved after February 1, 2013 are allocated on a hybrid cost allocation method approved by FERC and not subject to any court review. 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, Virginia Power will begin to make payments to PJM over the next 10 years under the terms of revised tariff records beginning in August 2018. Accordingly, at June 30, 2018, Virginia Power’s Consolidated Balance Sheet includes $148 million included in other current liabilities and $98 million included in other deferred credits and other liabilities, which are partially offset by a $237 million regulatory asset for the amount that will be recovered through retail rates in Virginia. FERC – Gas DETI 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’s 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) recorded within other operations and maintenance expense in Dominion Energy’s and Dominion Energy Gas’ Consolidated Statements of Income during the second quarter of 2017 to write-off the balance of a regulatory asset, originally established in 2008, that is no longer considered probable of recovery. DETI recognized a charge of $129 million ($94 million after-tax) recorded primarily within other operations and maintenance expense in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income during the second quarter of 2018 for a disallowance of plant, originally established beginning in 2012, in anticipation of resolution of one matter with FERC. Pending final resolution of the audit process and a determination by FERC, management is unable to estimate the potential impact of the remaining finding and no amounts have been recognized. 2017 Tax Reform Act 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 reduction as regulatory liabilities in January 2018 and will continue until rates are reset pursuant to state regulators’ approvals. The Companies have recorded a reasonable estimate of net income taxes refundable through future rates in the jurisdictions in which they operate and are currently assessing these actions and decisions, which could have a material impact on the Companies’ results of operations, financial condition and/or cash flows. In January 2018, the Virginia Commission issued an order directing Virginia utilities to reflect the impacts of the 2017 Tax Reform Act in the annual informational filings submitted to the Virginia Commission. Virginia Power submitted this filing in June 2018. Also, 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 Grid Transformation and Security Act of 2018. The interim rate reduction totals approximately $125 million on an annual basis effective July 2018. In February 2018, Virginia Power submitted a response to the North Carolina Utilities Commission detailing the impact of the 2017 Tax Reform Act on base non-fuel cost of service and Virginia Power’s excess deferred income taxes clarifying that the amounts have been deferred to a regulatory liability. In May 2018, the Utah Commission approved a stipulation submitted by Questar Gas proposing the cost-of-service component of customer rates be reduced by $15 million annually beginning in June 2018. The impact of excess deferred income taxes resulting from the 2017 Tax Reform Act on rates charged to customers will be reported to the Utah and Wyoming Commissions by the first quarter of 2019. In March 2018, East Ohio submitted responses to the Ohio Commission’s request for comments on those components of utility rates that will need to be reconciled with the 2017 Tax Reform Act, and on the process and mechanics by which the Ohio Commission should do so. This matter is pending. As directed by the Public Service Commission of West Virginia, 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. This matter is pending. In March 2018, FERC announced actions to address the income tax allowance component of regulated entities’ cost-of-service rates as a result of the 2017 Tax Reform Act. FERC issued a notice of proposed rulemaking introducing a process for determining whether jurisdictional natural gas pipelines may be collecting unjust and unreasonable rates as a result of the reduction in the corporate income tax rate. The proposed rule would require all interstate natural gas pipelines to make a one-time informational filing with FERC to provide financial information to allow FERC and other interested parties to analyze the impacts of the changes in tax law. The actions also included the reversal of FERC’s policy allowing master limited partnerships to recover an income tax allowance in cost-of-service rates and requiring other pass-through entities to justify the inclusion of an income tax allowance. FERC also issued a notice of inquiry seeking comments on whether it should take any additional actions to address changes in federal corporate income taxes, the elimination of an income tax allowance for master limited partnerships, excess or deficient accumulated deferred income taxes and bonus depreciation, among other items. 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. These procedures are generally the same as the proposals issued in March; however the final rule modifies the treatment of the income tax allowance for master limited partnerships and other pass-through entities in the informational filing. 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. Although the informational filing does not require the elimination of the income tax allowance for master limited partnerships, and provides options to master limited partnerships to address the income tax allowance that were previously unavailable including providing evidence that a double recovery of income taxes does not exist, there can be no assurance that master limited partnerships would be allowed to include an income tax allowance in the future. Given these developments and 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. Virginia Power’s regulated electric transmission formula rate mechanism includes provisions allowing changes in income tax rates to be incorporated in rates charged to customers. Other Regulatory Matters Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, and Note 13 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2018. Virginia Regulation 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. This matter is pending. Grid Transformation and Security Act of 2018 In March 2018, the Governor of Virginia signed into law legislation to reinstate 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 test periods beginning January 1, 2017 and ending December 31, 2020. This review for Virginia Power will occur one year earlier than under the Regulation Act legislation enacted in February 2015. 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 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. The legislation also includes provisions requiring Virginia Power to provide current customers one-time rate credits totaling $200 million and to reduce base rates to reflect reductions in income tax expense resulting from the 2017 Tax Reform Act. As a result, Virginia Power incurred a $215 million ($160 million after-tax) charge in connection with this legislation, including the impact on certain non-jurisdictional customers which follow Virginia Power’s jurisdictional customer rate methodology. In addition, Virginia Power will reduce 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 in April 2019. In July 2018, Virginia Power filed a petition with the Virginia Commission for approval of the first three years of its ten-year plan for electric distribution grid transformation projects as authorized by the Grid Transformation and Security Act of 2018. During the first three years of the plan, Virginia Power proposes to focus on the following seven foundational components of the overall grid transformation plan: (i) smart meters; (ii) customer information platform; (iii) reliability and resilience; (iv) telecommunications infrastructure; (v) cyber and physical security; (vi) predictive analytics; and (vii) emerging technology. The total estimated capital investment during 2019-2021 is $816 million and the proposed operations and maintenance expenses are $102 million. This matter is pending. 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, subject to true-up, for the rate year beginning September 1, 2018. This total revenue requirement represents a $146 million increase versus the revenues to be produced during the rate year under current rates. This matter is pending. • The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2018, Virginia Power proposed a $220 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $2 million increase over the previous year. This matter is pending. • The Virginia Commission previously approved Rider W in conjunction with Warren County. In June 2018, Virginia Power proposed a $107 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $2 million decrease over the previous year. This matter is pending. • The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2018, Virginia Power proposed a $59 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $7 million decrease over the previous year. This matter is pending. • The Virginia Commission previously approved Rider B in conjunction with the conversion of three power stations to biomass. In June 2018, Virginia Power proposed a $54 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $7 million increase over the previous year. This matter is pending. • The Virginia Commission previously approved Rider GV in conjunction with Greensville County. In June 2018, Virginia Power proposed a $121 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $39 million increase over the previous year. This matter is pending. • The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In October 2017, Virginia Power requested approval to extend one existing energy efficiency program for five years with a new $25 million cost cap, and proposed a total $31 million revenue requirement for the rate year beginning July 1, 2018, which represents a $3 million increase over the previous year. In May 2018, the Virginia Commission approved a total revenue requirement of $31 million, subject to true-up. • The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In October 2017, Virginia Power proposed a $132 million revenue requirement for the rate year beginning September 1, 2018, which represents a $5 million increase over the previous year. In July 2018, the Virginia Commission approved a $116 million revenue requirement, subject to true-up, for the rate year beginning September 1, 2018. • The Virginia Commission previously approved Rider US-2 in conjunction with Scott Solar, Whitehouse, and Woodland. In October 2017, Virginia Power proposed a $15 million revenue requirement for the rate year beginning September 1, 2018, which represents a $5 million increase over the previous year. In July 2018, the Virginia Commission approved a $13 million revenue requirement, subject to true-up, for the rate year beginning September 1, 2018. 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 associated with these projects with a proposed $11 million total revenue requirement for the rate year beginning March 1, 2019. This matter is pending. Electric Transmission Projects In July 2017, the National Parks Conservation Association filed a lawsuit in U.S. District Court for the District of Columbia seeking to set aside the permit granted by the U.S. Army Corps of Engineers for the Surry-to-Skiffes Creek-to-Whealton electric transmission line 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 and request for preliminary injunction in U.S. District Court for the District of Columbia. 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. Virginia Power previously filed an application with the Virginia Commission for a CPCN to convert an existing transmission line to 230 kV in Prince William County, Virginia, and Loudoun County, Virginia, and to construct and operate a new approximately five mile overhead 230 kV double circuit transmission line between a tap point near the Gainesville substation and a new to-be-constructed Haymarket substation. In June 2017, the Virginia Commission issued a final order approving an alternative route for the project, and granted the necessary CPCN. In July 2017, the Virginia Commission retained jurisdiction over the case to evaluate two requests to reconsider its decisions. Also in July 2017, Virginia Power requested that the Virginia Commission stay the proceeding while Virginia Power discussed the proposed route with leaders of Prince William County. In December 2017, the Virginia Commission granted in part the two motions for reconsideration, retained jurisdiction for further proceedings in the case and stayed the effectiveness of its final order. In March 2018, Virginia Power and the two parties seeking reconsideration entered into a stipulated settlement filed with the Virginia Commission agreeing that the project should be placed into an underground pilot program created by the Grid Transformation and Security Act of 2018. In June 2018, the Virginia Commission issued an order finding that the project is still needed. In July 2018, Virginia Power filed a request with the Virginia Commission to allow the project to participate in the underground pilot program. Subsequently, in July 2018, the Virginia Commission issued a final order granting the CPCN for the project and allowing the project to participate in the underground pilot program. In May 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in Chesterfield County and the City of Hopewell, Virginia approximately 8 miles of 230 kV transmission line between the Chesterfield and Hopewell substations, along with associated substation work. The total estimated cost of the project is approximately $30 million. This matter is pending. In May 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in Chesterfield and Henrico Counties, Virginia approximately 21 miles of 230 kV transmission line between the Chesterfield and Lakeside substations, along with associated substation work. The total estimated cost of the project is approximately $35 million. This matter is pending. In June 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in the Cities of Virginia Beach and Chesapeake, Virginia approximately 8.5 miles of 230 kV transmission line between the Landstown and Thrasher substations, along with associated substation work. The total estimated cost of the project is approximately $20 million. This matter is pending. 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. The total estimated cost of the project is approximately $35 million. This matter is pending. Ohio Regulation 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. The revised rider rate reflects recovery over the twelve-month period from July 2018 through June 2019 of projected deferred program costs of approximately $10 million from April 2018 through June 2019, net of a refund for over-recovery of accumulated arrearages of approximately $4 million as of March 31, 2018. This matter is pending. 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 May 2018, East Ohio filed an application with the Ohio Commission 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 approximately $16 million for the twelve-month period from April 2018 to March 2019. This matter is pending.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2018
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Variable Interest Entities	Note 14. Variable Interest Entities There have been no significant changes regarding the entities the Companies consider VIEs as described in Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. Dominion Energy Dominion Energy’s securities due within one year and long-term debt include $29 million and $324 million, respectively, of debt issued in 2016 by SBL Holdco, a VIE, net of issuance costs, that is nonrecourse to Dominion Energy and is secured by SBL Holdco’s interest in certain merchant solar facilities. Virginia Power Virginia Power had long-term power and capacity contracts with three non-utility generators. Contracts with two of these non-utility generators expired in the third quarter 2017 leaving a remaining aggregate summer generation capacity of approximately 218 MW. Virginia Power is not subject to any risk of loss from this potential VIE other than its remaining purchase commitments which totaled $175 million as of June 30, 2018. Virginia Power paid $12 million and $28 million for electric capacity and $5 million and $7 million for electric energy to non-utility generators in the three months ended June 30, 2018 and 2017, respectively. Virginia Power paid $25 million and $56 million for electric capacity and $10 million and $15 million for electric energy to non-utility generators in the six months ended June 30, 2018 and 2017, respectively. Virginia Power and Dominion Energy Gas Virginia Power and Dominion Energy Gas purchased shared services from DES, an affiliated VIE, of $83 million and $31 million for the three months ended June 30, 2018, $83 million and $31 million for the three months ended June 30, 2017, $172 million and $63 million for the six months ended June 30, 2018 and $168 million and $62 million for the six months ended June 30, 2017, respectively. Virginia Power and Dominion Energy Gas’ Consolidated Balance Sheets included amounts due to DES of $35 million and $12 million, respectively, at June 30, 2018, and $36 million and $14 million, respectively, at December 31, 2017, recorded in payables to affiliates in the Consolidated Balance Sheets.

Significant Financing Transacti

Significant Financing Transactions	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Significant Financing Transactions	Note 15. Significant Financing Transactions Credit Facilities and Short-term Debt 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. Dominion Energy In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. At June 30, 2018, Dominion Energy’s commercial paper and letters of credit outstanding, as well as its capacity available under the credit facility, were as follows: Facility Limit Outstanding Commercial Paper Outstanding Letters of Credit Facility Capacity Available (millions) Joint revolving credit facility (1) $ 6,000 $ 2,743 $ 72 $ 3,185 (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. Questar Gas’ short-term financing is supported through its access as co-borrower to the joint revolving credit facility discussed above with Dominion Energy, Virginia Power and Dominion Energy Gas. At June 30, 2018, the sub-limit for Questar Gas was $250 million. In addition to the credit facility mentioned above, SBL Holdco has $30 million of credit facilities which had an original stated maturity date of December 2017 with automatic one-year renewals through the maturity of the SBL Holdco term loan agreement in 2023. Dominion Solar Projects III, Inc. has $25 million of credit facilities which had an original stated maturity date of May 2018 with automatic one-year renewals through the maturity of the Dominion Solar Projects III, Inc. term loan agreement in 2024. At June 30, 2018, no amounts were outstanding under either of these facilities. In February 2018, Dominion Energy borrowed $950 million under a 364-Day Term Loan Agreement that bears interest at a variable rate. In addition, the agreement contains a maximum allowed total debt to total capital ratio of 67.5%. In March 2018, Dominion Energy Midstream entered into a $500 million revolving credit facility. The credit facility matures in March 2021, bears interest at a variable rate, and can be 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 June 30, 2018, Dominion Energy Midstream had $73 million outstanding under this credit facility. In June 2018, Dominion Energy borrowed $500 million under a 364-Day Term Loan Agreement that bears interest at a variable rate. In addition, the agreement contains a maximum allowed total debt to total capital ratio of 67.5%. Virginia Power Virginia Power’s short-term financing is supported through its access as co-borrower to the joint revolving credit facility. This credit facility can be used for working capital, as support for the combined commercial paper programs of the Companies and for other general corporate purposes. At June 30, 2018, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Dominion Energy Gas and Questar Gas was as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) Joint revolving credit facility (1) $ 6,000 $ 1,158 $ 1 (1) 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 June 30, 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. 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 financings supported by this credit facility and terminated the facility. Dominion Energy Gas Dominion Energy Gas’ short-term financing is supported through its access as co-borrower to the joint revolving credit facility. This credit facility can be used for working capital, as support for the combined commercial paper programs of the Companies and for other general corporate purposes. At June 30, 2018, Dominion Energy Gas' share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Virginia Power and Questar Gas was as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) Joint revolving credit facility (1) $ 1,500 $ 188 $ — (1) 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 Long-term Debt Unless otherwise noted, the proceeds of long-term debt issuances were used for general corporate purposes and/or to repay short-term debt. In January 2018, Dominion Energy Questar Pipeline issued, through private placement, $100 million of 3.53% senior notes and $150 million of 3.91% senior notes that mature in 2028 and 2038, respectively. The proceeds were used to repay maturing long-term debt. In March 2018, Virginia Power issued $700 million of 3.80% senior notes that mature in 2028. In March 2018, Virginia Power redeemed $100 million of its variable rate tax-exempt financings which would otherwise have matured in 2024, 2026 and 2027. In April 2018, Questar Gas issued through private placement $50 million of 3.30% senior notes and $100 million of 3.97% senior notes that mature in 2030 and 2047, respectively. In May 2018, Dominion Energy issued through private placement $500 million of variable rate senior notes that mature in 2020. In June 2018, Dominion Energy issued $300 million of 4.25% senior notes that mature in 2028. In June 2018, Dominion Energy Gas issued $500 million of variable rate senior notes that mature in 2021. Noncontrolling Interest in Dominion Energy Midstream 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 27 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 corresponding 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. Issuance of Common Stock At-the-Market Programs In June 2017, Dominion Energy filed an SEC shelf registration statement for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program. Also, in June 2017, Dominion Energy entered into three separate sales agency agreements to effect sales under the program and pursuant to which it was able to offer up to $500 million aggregate amount of its common stock. In January 2018, Dominion Energy provided sales instructions to one of the sales agents and issued 6.6 million shares through at-the-market issuances and received cash proceeds of $495 million, net of fees and commissions paid of $5 million. Following these issuances, Dominion Energy had no remaining ability to issue stock under the 2017 sales agency agreements and completed the program. In February 2018, Dominion Energy entered into six separate sales agency agreements to effect sales under a new at-the-market program pursuant to which it may offer from time to time up to $1.0 billion aggregate amount of its common stock. These agreements replaced the sales agency agreements entered into by Dominion Energy in June 2017. Sales of common stock can be made by means of privately negotiated transactions, as transactions on the New York Stock Exchange at market prices or in such other transactions as are agreed upon by Dominion Energy and the sales agents in conformance with applicable securities laws. No issuances have occurred under these agreements and none are planned in 2018. Forward Sales Agreements 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 option to purchase up to an additional three million shares of Dominion Energy common stock, which the underwriters exercised with respect to approximately 2.1 million shares in April 2018. Dominion Energy entered into separate forward sale agreements with the forward purchasers with respect to the additional shares. Except in certain specified circumstances that would require physical share settlement, Dominion Energy may elect physical, cash or net share settlement of the forward sale agreements on or before December 31, 2018. At the initial forward sale price of approximately $67.33 per share, Dominion Energy expects the net proceeds from full physical settlement of the forward sales agreements to be approximately $1.5 billion (after deducting underwriting discounts, but before deducting expenses, and subject to forward price adjustments under the forward sale agreements). Pursuant to a cash settlement of the forward sale agreements, Dominion Energy would expect to receive an amount of net proceeds that is significantly lower than estimated above in connection with the full physical settlement, and Dominion Energy may not receive any net proceeds (or may owe cash, which could be a significant amount, to the forward purchasers). If the forward sale agreements are net share settled in full, Dominion Energy would not receive any cash proceeds from the forward purchasers (and may be required to deliver shares of our common stock to the forward purchasers). The forward sale transactions will be classified as equity transactions, because they are indexed to Dominion Energy’s common stock and physical settlement is within Dominion Energy’s control.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2018
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 16. 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 for which the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the Companies’ maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the 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. Air 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 electric utility steam generating units to meet strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. Following a one-year compliance extension granted by the VDEQ and an additional one-year extension under an EPA Administrative Order, Virginia Power ceased operating the coal units at Yorktown power station in April 2017 to comply with the rule. 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 approximately 23 months following the receipt in July 2017 of final permits and approvals for construction. Beginning in August 2017, PJM filed requests for 90-day renewals of the DOE order, which the DOE has granted. The current renewal is effective until September 2018. The Sierra Club has challenged the DOE order and certain renewal requests, all of which have been denied by the DOE. Although litigation of the MATS rule is 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 to 70-ppb. To comply with this standard, in April 2016 Virginia Power submitted the NO X X X X The EPA published final non-attainment designations for the October 2015 ozone standard in June 2018. States have until August 2021 to develop plans to address the new standard. Until the states have developed implementation plans for the standard, the Companies are unable to predict whether or to what extent the new rules will ultimately require additional controls. The expenditures required to implement additional controls could have a material impact on the Companies’ results of operations and cash flows. 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 April 2017, the EPA issued a notice that it is reviewing the rule and, if appropriate, will issue a rulemaking to suspend, revise or rescind the June 2016 final NSPS for certain oil and gas facilities. In June 2017, the EPA published notice of reconsideration and partial stay of the rule for 90 days and proposed extending the stay for two years. In July 2017, the U.S. Court of Appeals for the D.C. Circuit vacated the 90-day stay. In November 2017, the EPA solicited comments on the proposed two-year stay of the June 2016 NSPS rules. 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 Regulation 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, or conventional, pollutants that are regulated by the New Source Review program, and to set a significant emissions rate at 75,000 tons per year of CO 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. DECG joined the EPA’s voluntary Natural Gas STAR Program in July 2016 and submitted an implementation plan in September 2016. 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. Water The CWA, as amended, is a comprehensive program requiring a broad range of regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. The Companies must comply with applicable aspects of the CWA programs at their operating facilities. In October 2014, the final regulations under Section 316(b) of the CWA that govern existing facilities and new units at existing facilities that employ a cooling water intake structure and that have flow levels exceeding a minimum threshold became effective. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the creation of a single technology standard for entrainment. Instead, the EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above two MGD, with a heightened entrainment analysis for those facilities over 125 MGD. Dominion Energy and Virginia Power have 13 and 11 facilities, respectively, that may be subject to the final regulations. Nine units at Virginia Power’s facilities that are subject to regulations under Section 316(b) of the CWA have been or will be placed into cold reserve. While in cold reserve, applicable requirements under Section 316(b) of the CWA continue to apply to these units. Dominion Energy anticipates that it will have to install impingement control technologies at many of these stations that have once-through cooling systems. Dominion Energy and Virginia Power are currently evaluating the need or potential for entrainment controls under the final rule as these decisions will be made on a case-by-case basis after a thorough review of detailed biological, technology, cost and benefit studies. While the impacts of this rule could be material to Dominion Energy’s and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power. In September 2015, the EPA released a final rule to revise the Effluent Limitations Guidelines for the Steam Electric Power Generating Category. The final rule establishes updated standards for wastewater discharges that apply primarily at coal and oil steam generating stations. Affected facilities are required to convert from wet to dry or closed cycle coal ash management, improve existing wastewater treatment systems and/or install new wastewater treatment technologies in order to meet the new discharge limits. Virginia Power has eight facilities subject to the final rule. 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’s and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power. Waste Management and Remediation The CERCLA, as amended, provides for immediate response and removal actions coordinated by the EPA in the event of threatened releases of hazardous substances into the environment and authorizes the U.S. government either to clean up sites at which hazardous substances have created actual or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be jointly, severally and strictly liable for the cost of cleanup. These potentially responsible parties can be ordered to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight. From time to time, Dominion 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 19 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 two 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 late 2018. As a result, in June 2018, Virginia Power recorded a charge of $16 million ($12 million after-tax) in other operations and maintenance expense in the Consolidated Statements of Income. Due to the uncertainty surrounding the other sites, the Companies are unable to make an estimate of the potential financial statement impacts. See below for discussion on ash pond and landfill closure costs. Other Legal Matters The Companies are defendants in a number of lawsuits and claims involving unrelated incidents of property damage and personal injury. Due to the uncertainty surrounding these matters, the Companies are unable to make an estimate of the potential financial statement impacts; however, they could have a material impact on results of operations, financial condition and/or cash flows. Appalachian Gateway 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. This case is pending. At June 30, 2018, DETI has accrued a liability of $14 million for this matter, recorded in other current liabilities in the Consolidated Balance Sheets. Dominion Energy Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows. 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. All other 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. Ash Pond and Landfill Closure Costs 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 coal ash storage units was migrating to adjacent surface water, which constituted an unpermitted point source discharge in violation of the CWA. The court, however, rejected Sierra Club’s claims that Virginia Power had violated specific conditions of its water discharge permit. Finding no harm to the environment, the court further declined to impose civil penalties or require excavation of the ash from the site as Sierra Club had sought. In July 2017, the court issued a final order requiring Virginia Power to perform additional specific sediment, water and aquatic life monitoring at and around the Chesapeake power station for a period of at least two years. The court further directed Virginia Power to apply for a solid waste permit from the VDEQ that includes corrective measures to address on-site groundwater impacts. In July 2017, Virginia Power appealed the court’s July 2017 final order to the U.S. Court of Appeals for the Fourth Circuit. In August 2017, the Sierra Club filed a cross appeal. This case is pending. 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. Virginia Power currently operates inactive ash ponds, existing ash ponds, and CCR landfills subject to the final rule at eight different facilities. This rule created a legal obligation for Virginia Power to retrofit or close all of its inactive and existing ash ponds over a certain period of time, as well as perform required monitoring, corrective action, and post-closure care activities as necessary. In December 2016, legislation was enacted that creates a framework for EPA-approved state CCR permit programs. In August 2017, the EPA issued interim guidance outlining the framework for state CCR program approval. The EPA has enforcement authority until state programs are approved. The EPA and states with approved programs both will have authority to enforce CCR requirements under their respective rules and programs. In September 2017, the EPA agreed to reconsider portions of the CCR rule in response to two petitions for reconsideration. Litigation concerning the CCR rule is pending and the EPA has submitted to the court a list of which CCR rule provisions the EPA intends to reevaluate. In March 2018, the EPA proposed certain changes to the CCR rule related to issues remanded as part of the pending litigation and other issues the EPA is reconsidering. Several of the proposed changes would allow states with approved CCR permit programs additional flexibilities in implementing their programs. In July 2018, the EPA promulgated the first phase of changes to the CCR rule. Any changes to the CCR rule would not be effective in Virginia unless and until the VDEQ adopts those changes. Until all phases of the CCR rule are promulgated, Virginia Power cannot forecast potential incremental impacts or costs related to existing coal ash sites in connection with future implementation of the 2016 CCR legislation and reconsideration of the CCR rule. In April 2017, the Governor of Virginia signed legislation into law that placed 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 requires 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 disposal, surface and groundwater conditions and safety. Virginia Power completed the assessments and provided the report on December 1, 2017. In April 2018, the Governor of Virginia signed legislation into law extending the existing permit moratorium until July 2019. The legislation also requires Virginia Power to solicit and compile by November 2018, information from third parties on the suitability, cost and market demand for beneficiation or recycling of coal ash from these units. The extended moratorium does not apply to a permit required for an impoundment where CCRs have already been removed and placed in another impoundment on-site, are being removed from an impoundment, or are being processed in connection with a recycling or beneficial use project. In connection with this legislation, Virginia Power recorded an increase to its ARO and a related environmental liability related to future ash pond and landfill closure costs of $131 million, which resulted in an $81 million ($60 million after-tax) charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $46 million increase in property, plant and equipment associated with asset retirement costs and a $4 million increase in regulatory assets. The actual AROs related to the CCR rule may vary substantially from the estimates used to record the obligation. Cove Point 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. Separately, one party requested a stay of the FERC order until the judicial proceedings are complete, which the court denied in June 2015. 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. This case is pending. FERC FERC staff in the Office of Enforcement, Division of Investigations, is conducting a non-public investigation of Virginia Power's offers of combustion turbines generators into the PJM day-ahead markets from April 2010 through September 2014. FERC staff notified Virginia Power of its preliminary findings relating to Virginia Power's alleged violation of FERC's rules in connection with these activities. Virginia Power has provided its response to FERC staff's preliminary findings letter explaining why Virginia Power's conduct was lawful and refuting any allegation of wrongdoing. Virginia Power is cooperating fully with the investigation; however, it cannot currently predict whether or to what extent it may incur a material liability. 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 methods and information, conduct walkdowns of their facilities to ensure protection against the hazards in their current design basis, and to reevaluate their emergency communications systems and staffing levels. The walkdowns of each unit have been completed, audited by the NRC and found to be adequate. Reevaluation of the emergency communications systems and staffing levels was completed as part of the effort to comply with the orders. Reevaluation of the seismic and external flooding hazards is expected to continue through 2018. Dominion Energy and Virginia Power do not currently expect that compliance with the NRC's information requests will materially impact their financial position, results of operations or cash flows during the implementation period. The NRC staff is evaluating the implementation of the longer-term Tier 2 and Tier 3 recommendations. Dominion Energy and Virginia Power do not expect material financial impacts related to compliance with Tier 2 and Tier 3 recommendations. Nuclear Operations Nuclear Insurance 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. This decrease does not impact Dominion Energy’s responsibility per active unit under the Price-Anderson Amendments Act of 1988. Spent Nuclear Fuel 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’s 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, 2016, and have been extended to provide for periodic payment of damages 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. Guarantees, Surety Bonds and Letters of Credit Dominion Energy In October 2017, Dominion Energy entered into a guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under a $3.4 billion revolving credit facility, also entered in October 2017, with a stated maturity date of October 2021. Dominion Energy’s maximum potential loss exposure under the terms of the guarantee is limited to 48% of the outstanding borrowings under the revolving credit facility, an equal percentage to Dominion Energy’s ownership in Atlantic Coast Pipeline. As of June 30, 2018, Atlantic Coast Pipeline has borrowed $877 million against the revolving credit facility. Dominion Energy’s Consolidated Balance Sheets include a liability of $30 million associated with this guarantee agreement at June 30, 2018. In addition, at June 30, 2018, Dominion Energy had issued $48 million Dominion Energy also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. At June 30, 2018, Dominion Energy had issued the following subsidiary guarantees: Maximum Exposure (millions) Commodity transactions (1) $ 2,142 Nuclear obligations (2) 200 Cove Point (3) 1,900 Solar (4) 636 Other (5) 577 Total (6) $ 5,455 (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,

Credit Risk

Credit Risk	6 Months Ended
	Jun. 30, 2018
Risks And Uncertainties [Abstract]
Credit Risk	Note 17. Credit Risk The Companies’ accounting policies for credit risk are discussed in Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017 At June 30, 2018, Dominion Energy’s gross credit exposure related to energy marketing and price risk management activities totaled $67 million. Of this amount, investment grade counterparties, including those internally rated, represented 30%. No single counterparty, whether investment grade or non-investment grade, exceeded $7 million of exposure. At June 30, 2018, Virginia Power’s exposure related to wholesale customers totaled $52 million. Of this amount, investment grade counterparties, including those internally rated, represented 24%. No single counterparty, whether investment grade or non-investment grade, exceeded $9 million of exposure. At June 30, 2018, Dominion Energy Gas’ exposure primarily related to wholesale customers totaled less than $1 million. Of this amount, investment grade counterparties, including those internally rated, represented 82%. No single counterparty, whether investment grade or non-investment grade, exceeded $1 million of exposure. 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 June 30, 2018 and December 31, 2017, Dominion Energy would have been required to post $11 million and $62 million, respectively, of additional collateral to its counterparties. The collateral that would be required to be posted includes the impacts of any offsetting asset positions and any amounts already posted for derivatives, non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. Dominion Energy had posted no collateral at June 30, 2018 or December 31, 2017 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The aggregate fair value of all derivative instruments with credit-related contingent provisions that are in a liability position and not fully collateralized with cash at June 30, 2018 and December 31, 2017 was $13 million and $65 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Energy Gas were not material as of June 30, 2018 and December 31, 2017. See Note 9 for further information about derivative instruments.

Related-Party Transactions

Related-Party Transactions	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Related-Party Transactions	Note 18. Related-Party Transactions Virginia Power and Dominion Energy Gas engage in related-party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia Power's 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. Dominion Energy’s transactions with equity method investments are described in Note 10. A discussion of significant related-party transactions follows. Virginia Power Transactions with Affiliates Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of commodity swaps, to manage commodity price risks associated with purchases of natural gas. At June 30, 2018, Virginia Power’s derivative assets and liabilities with affiliates were $9 million and $5 million, respectively. At December 31, 2017, Virginia Power’s derivative assets and liabilities with affiliates were $11 million and $5 million, respectively. See Note 9 for more information. Virginia Power participates in certain Dominion Energy benefit plans described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. At June 30, 2018 and December 31, 2017, amounts due to Dominion Energy associated with the Dominion Energy Pension Plan and included in other deferred credits and other liabilities in the Consolidated Balance Sheets were $569 million and $505 million, respectively. At June 30, 2018 and December 31, 2017, Virginia Power's amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan and included in other deferred charges and other assets in the Consolidated Balance Sheets were $236 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 Virginia Power’s significant transactions with DES and other affiliates: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Commodity purchases from affiliates $ 139 $ 137 $ 537 $ 349 Services provided by affiliates (1) 112 112 232 224 Services provided to affiliates 5 7 11 12 (1) Includes capitalized expenditures of Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were $25 million and $33 million in short-term demand note borrowings from Dominion Energy as of June 30, 2018 and December 31, 2017, respectively. Virginia Power had no outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated subsidiaries as of June 30, 2018 and December 31, 2017. Interest charges related to Virginia Power’s borrowings from Dominion Energy were less than $1 million for the three and six months ended June 30, 2018 and 2017. There were no issuances of Virginia Power’s common stock to Dominion Energy for the three and six months ended June 30, 2018 and 2017. Dominion Energy Gas 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 June 30, 2018, Dominion Energy Gas had no derivative assets and $7 million of derivative liabilities with affiliates. As of December 31, 2017, all of Dominion Energy Gas' commodity derivatives were with affiliates. See Notes 7 and 9 for more information. See Note 10 for information regarding transactions with Atlantic Coast Pipeline. Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed on June 6, 2018. At June 30, 2018 and December 31, 2017, amounts due from Dominion Energy associated with the Dominion Energy Pension Plan included in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $753 million and $734 million, respectively. At June 30, 2018 and December 31, 2017, Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan included in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $10 million and $7 million, respectively. 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. Presented below are Dominion Energy Gas’ significant transactions with DES and other affiliates and related parties: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Sales of natural gas and transportation and storage services to affiliates $ 16 $ 18 $ 34 $ 36 Purchases of natural gas from affiliates (2 ) 1 1 — Services provided by related parties (1) 33 36 66 73 Services provided to related parties (2) 61 36 113 75 (1) Includes capitalized expenditures of $7 million and $12 million for the three months ended June 30, 2018 and 2017, respectively, and $17 million and $20 million for the six months ended June 30, 2018 and 2017, 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: June 30, 2018 December 31, 2017 (millions) Other receivables (1) $ 19 $ 12 Customer receivables from related parties — 1 Imbalances receivable from affiliates — 1 Imbalances payable to affiliates (2) 5 — Affiliated notes receivable (3) 18 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 intercompany revolving credit agreement with Dominion Energy were $56 million and $18 million as of June 30, 2018 and December 31, 2017, respectively. Interest charges related to Dominion Energy Gas’ total borrowings from Dominion Energy were immaterial for the three and six months ended June 30, 2018 and 2017.

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2018
Compensation And Retirement Disclosure [Abstract]
Employee Benefit Plans	Note 19. Employee Benefit Plans Dominion Energy The components of Dominion Energy’s provision for net periodic benefit cost (credit) were as follows: Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 (millions) Three Months Ended June 30, Service cost $ 40 $ 34 $ 6 $ 6 Interest cost 84 87 14 14 Expected return on plan assets (168 ) (161 ) (35 ) (31 ) Amortization of prior service cost (credit) 1 1 (13 ) (13 ) Amortization of net actuarial loss 49 41 2 3 Net periodic benefit cost (credit) $ 6 $ 2 $ (26 ) $ (21 ) Six Months Ended June 30, Service cost $ 79 $ 69 $ 13 $ 13 Interest cost 168 173 28 30 Expected return on plan assets (333 ) (320 ) (71 ) (63 ) Amortization of prior service cost (credit) 1 1 (26 ) (25 ) Amortization of net actuarial loss 97 81 5 6 Settlements — 1 — — Net periodic benefit cost (credit) $ 12 $ 5 $ (51 ) $ (39 ) Employer Contributions During the six months ended June 30, 2018, Dominion Energy made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Energy expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2018. Dominion Energy Gas Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018. See Note 18 for more information. The components of Dominion Energy Gas’ provision for net periodic benefit cost (credit) for employees represented by collective bargaining units were as follows: Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 (millions) Three Months Ended June 30, Service cost $ 5 $ 4 $ 1 $ 1 Interest cost 7 8 2 3 Expected return on plan assets (38 ) (36 ) (6 ) (6 ) Amortization of prior service credit — — (1 ) (1 ) Amortization of net actuarial loss 5 4 1 — Net periodic benefit credit $ (21 ) $ (20 ) $ (3 ) $ (3 ) Six Months Ended June 30, Service cost $ 9 $ 8 $ 2 $ 2 Interest cost 14 15 5 6 Expected return on plan assets (75 ) (71 ) (14 ) (12 ) Amortization of prior service credit — — (2 ) (1 ) Amortization of net actuarial loss 10 8 2 1 Net periodic benefit credit $ (42 ) $ (40 ) $ (7 ) $ (4 ) Employer Contributions During the six months ended June 30, 2018, Dominion Energy Gas made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Energy Gas expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs, for both employees represented by collective bargaining units and employees not represented by collective bargaining units, during the remainder of 2018.

Operating Segments

Operating Segments	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Operating Segments	Note 20. Operating Segments The Companies are organized primarily on the basis of products and services sold in the U.S. A description of the operations included in the Companies’ primary operating segments is as follows: Primary Operating Segment Description of Operations Dominion Energy Virginia Power Dominion Energy Gas Power Delivery Regulated electric distribution X X Regulated electric transmission X X Power Generation Regulated electric fleet X X Merchant electric fleet X Gas Infrastructure Gas transmission and storage X X Gas distribution and storage X X Gas gathering and processing X X LNG terminalling and storage X Nonregulated retail energy marketing X In addition to the operating segments above, the Companies also report a Corporate and Other segment. Dominion Energy The Corporate and Other Segment of Dominion Energy 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. In the six months ended June 30, 2018, Dominion Energy reported after-tax net expenses of $349 million for specific items in the Corporate and Other segment, with $310 million of net expenses attributable to its operating segments. In the six months ended June 30, 2017, Dominion Energy reported after-tax net expenses of $10 million for specific items in the Corporate and Other segment, with $1 million of net expenses attributable to its operating segments. The net expense for specific items attributable to Dominion Energy’s operating segments in 2018 primarily related to the impact of the following items: • A $215 million ($160 million after-tax) charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers, attributable to: • Power Generation ($109 million after-tax); and • Power Delivery ($51 million after-tax). • A $122 million ($89 million after tax) charge for disallowance of FERC-regulated plant attributable to Gas Infrastructure. • An $81 million ($60 million after-tax) charge associated primarily with the asset retirement obligations for ash ponds and landfills at certain utility generation facilities in connection with the enactment of Virginia legislation in April 2018 attributable to Power Generation. The following table presents segment information pertaining to Dominion Energy’s operations: Power Delivery Power Generation Gas Infrastructure Corporate and Other Adjustments/ Eliminations Consolidated Total (millions) Three Months Ended June 30, 2018 Total revenue from external customers $ 528 $ 1,635 $ 914 $ (3 ) $ 14 $ 3,088 Intersegment revenue 6 3 8 170 (187 ) — Total operating revenue 534 1,638 922 167 (173 ) 3,088 Net income (loss) attributable to Dominion Energy 145 276 249 (221 ) — 449 Three Months Ended June 30, 2017 Total revenue from external customers $ 530 $ 1,507 $ 589 $ 6 $ 181 $ 2,813 Intersegment revenue 7 2 175 149 (333 ) — Total operating revenue 537 1,509 764 155 (152 ) 2,813 Net income (loss) attributable to Dominion Energy 127 240 163 (140 ) — 390 Six Months Ended June 30, 2018 Total revenue from external customers $ 1,091 $ 3,495 $ 2,136 $ (210 ) $ 42 $ 6,554 Intersegment revenue 12 5 14 345 (376 ) — Total operating revenue 1,103 3,500 2,150 135 (334 ) 6,554 Net income (loss) attributable to Dominion Energy 301 624 576 (549 ) — 952 Six Months Ended June 30, 2017 Total revenue from external customers $ 1,084 $ 3,160 $ 1,490 $ 9 $ 454 $ 6,197 Intersegment revenue 12 5 441 301 (759 ) — Total operating revenue 1,096 3,165 1,931 310 (305 ) 6,197 Net income (loss) attributable to Dominion Energy 252 501 426 (157 ) — 1,022 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. Virginia Power The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating segments that are not included in profit measures evaluated by executive management in assessing the segments' performance or in allocating resources. In the six months ended June 30, 2018, Virginia Power reported after-tax net expenses of $237 million for specific items in the Corporate and Other segment, with $230 million of net expenses attributable to its operating segments. In the six months ended June 30, 2017, Virginia Power reported after-tax net expenses of $7 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments. The net expense for specific items attributable to Virginia Power’s operating segments in 2018 primarily related to the impact of the following items: • A $215 million ($160 million after-tax) charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers, attributable to: • Power Generation ($109 million after-tax); and • Power Delivery ($51 million after-tax). • An $81 million ($60 million after-tax) charge associated primarily with the asset retirement obligations for ash ponds and landfills at certain utility generation facilities in connection with the enactment of Virginia legislation in April 2018 attributable to Power Generation. The net expense for specific items attributable to Virginia Power’s operating segments in 2017 primarily related to the impact of the following item which was attributable to Power Delivery: • A $16 million ($10 million after-tax) charge arising from a proposed customer settlement. The following table presents segment information pertaining to Virginia Power’s operations: Power Delivery Power Generation Corporate and Other Consolidated Total (millions) Three Months Ended June 30, 2018 Operating revenue $ 528 $ 1,301 $ — $ 1,829 Net income (loss) 145 227 (33 ) 339 Three Months Ended June 30, 2017 Operating revenue $ 533 $ 1,214 $ — $ 1,747 Net income (loss) 125 198 (5 ) 318 Six Months Ended June 30, 2018 Operating revenue $ 1,091 $ 2,701 $ (215 ) $ 3,577 Net income (loss) 299 449 (225 ) 523 Six Months Ended June 30, 2017 Operating revenue $ 1,090 $ 2,488 $ — $ 3,578 Net income 250 421 3 674 Dominion Energy Gas The Corporate and Other Segment of Dominion Energy Gas primarily includes specific items attributable to Dominion Energy Gas’ 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. In the six months ended June 30, 2018, Dominion Energy Gas reported after-tax net expenses of $91 million for specific items in the Corporate and Other segment, with $89 million of net expenses attributable to its operating segment. In the six months ended June 30, 2017, Dominion Energy Gas reported after-tax net expenses of $9 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment. The net expense for specific items in 2018 was due to a $122 million ($89 million after-tax) charge for disallowance of FERC-regulated plant. The net expense for specific items in 2017 was due to a $15 million ($9 million after-tax) charge to write-off the balance of a regulatory asset no longer considered probable of recovery at June 30, 2017. The following table presents segment information pertaining to Dominion Energy Gas’ operations: Gas Infrastructure Corporate Other Consolidated Total (millions) Three Months Ended June 30, 2018 Operating revenue $ 459 $ — $ 459 Net income (loss) 108 (93 ) 15 Three Months Ended June 30, 2017 Operating revenue $ 422 $ — $ 422 Net income (loss) 88 (11 ) 77 Six Months Ended June 30, 2018 Operating revenue $ 985 $ — $ 985 Net income (loss) 275 (94 ) 181 Six Months Ended June 30, 2017 Operating revenue $ 912 $ — $ 912 Net income (loss) 197 (12 ) 185

Significant Accounting Polici29

Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of Accounting	As permitted by the rules and regulations of the SEC, the Companies’ accompanying unaudited Consolidated Financial Statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018.
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 and expenses for the periods presented. Actual results may differ from those estimates.
Consolidation	The Companies’ accompanying unaudited Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned entities in which they have a controlling financial interest.
Consolidation, consolidated entities and noncontrolling interest	For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. At June 30, 2018, Dominion Energy owns the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy Midstream. The public’s ownership interest in Dominion Energy Midstream is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Also, at June 30, 2018, Dominion Energy owns 50% of the units in and consolidates Four Brothers and Three Cedars. NRG’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy merchant solar projects, is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements.
Reclassifications	Certain amounts in the Companies’ 2017 Consolidated Financial Statements and Notes have been reclassified as a result of the adoption of revised accounting guidance pertaining to certain net periodic pension and other postretirement benefit costs, restricted cash and equivalents and certain distributions from equity method investees. In addition, certain other amounts 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
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 include accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to utility customers. Virginia Power’s customer receivables include accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to customers. Dominion Energy Gas’ customer receivables include accrued unbilled revenue based on estimated amounts of natural gas delivered and services provided but not yet billed to customers. 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: Revenue from Contracts with Customers • Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated hedging activity; • Regulated gas sales consist primarily of state-regulated natural gas sales and related distribution services; • Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties and associated hedging activity; • Regulated gas transportation and storage sales consist of FERC-regulated sales of transmission and storage services and state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • Nonregulated gas transportation and storage sales consist primarily of LNG terminalling services; • Other regulated revenue consists primarily of miscellaneous service revenue from electric and gas distribution operations and sales of excess electric capacity and other commodities; and • Other nonregulated revenue consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity. Other nonregulated revenue also includes services performed for Atlantic Coast Pipeline, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations, service concession arrangements and gas processing and handling revenue. Other Revenue • Other revenue consists primarily of alternative revenue programs, gains and losses from derivative instruments not subject to hedge accounting and lease revenues. 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 consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Nonregulated electric sales consisted primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity; • Regulated gas sales consisted primarily of state- and FERC-regulated natural gas sales and related distribution services and associated derivative activity; • Nonregulated gas sales consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity; • Gas transportation and storage sales consisted primarily of FERC-regulated sales of transmission and storage services. Also included were state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; and • Other revenue consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also included miscellaneous service revenue from electric and gas distribution operations, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations and gas processing and handling 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: Revenue from Contracts with Customers • Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; • Other regulated revenue consists primarily of sales of excess capacity and other commodities and miscellaneous service revenue from electric distribution operations; and • Other nonregulated revenue consists primarily of sales to non-jurisdictional customers from certain solar facilities, revenue from renting space on certain electric transmission poles and distribution towers and service concession arrangements. Other Revenue • Other revenue consists primarily of alternative revenue programs and gains and losses from derivative instruments not subject to hedge accounting. 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 consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; and • Other revenue consisted primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities. The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows: Revenue from Contracts with Customers • Regulated gas sales consist primarily of state-regulated natural gas sales and related distribution services; • Nonregulated gas sales consist primarily of sales of gas purchased from third parties and royalty revenues; • Regulated gas transportation and storage sales consist of FERC-regulated sales of transmission and storage services and state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • NGL revenue consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity; • Management service revenue consists primarily of services performed for Atlantic Coast Pipeline; • Other regulated revenue consists primarily of miscellaneous regulated revenues; and • Other nonregulated revenue consists primarily of miscellaneous service revenue. Other Revenue • Other revenue consists primarily of gains and losses from derivative instruments not subject to hedge accounting. 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 consisted primarily of state- and FERC-regulated natural gas sales and related distribution services; • Nonregulated gas sales consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices and sales of gas purchased from third parties. Revenue from sales of gas production was recognized based on actual volumes of gas sold to purchasers and was reported net of royalties; • Gas transportation and storage sales consisted primarily of FERC-regulated sales of transmission and storage services. Also included were state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; • NGL revenue consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity; and • Other revenue consisted primarily of miscellaneous service revenue, gas processing and handling revenue. 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. Currently, Dominion Energy and Virginia Power account for the equity return for under-recovery of certain riders under the alternative revenue program guidance. 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 phase of the Liquefaction Project. Fixed fees are recognized ratably over the life of the contract as the stand-ready performance obligation is satisfied, while variable usage fees are recognized when Dominion Energy and Dominion Energy Gas have a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the performance obligation completed to date. Sales of products, such as NGLs, typically transfer control and are recognized as revenue upon delivery of the product. The customer is able to direct the use of, and obtain substantially all of the benefits from, the product at the time the product is delivered. The contract with the customer states the final terms of the sale, including the description, quantity and price of each product or service purchased. Payment for most sales and services varies by contract type, but is typically due within a month of billing. 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.
Cash, Restricted Cash and Equivalents	Cash, Restricted Cash and Equivalents Restricted Cash and Equivalents The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for certain customer deposits, future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements and a distribution reserve at Cove Point. Upon adoption of revised accounting guidance in January 2018, restricted cash and equivalents are included within the Companies’ Consolidated Statements of Cash Flows, with the change in balance no longer considered a separate investing activity. The guidance required retrospective application which resulted in an adjustment to Dominion Energy and Dominion Energy Gas’ other cash provided by (used in) investing activities for the six months ended June 30, 2017, which had been previously reported as $4 million and $(11) million, respectively. There was no impact to Virginia Power for the six months ended June 30, 2017. 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 six months ended June 30, 2018 and 2017: Cash, Restricted Cash and Equivalents at End of Period Cash, Restricted Cash and Equivalents at Beginning of Period June 30, 2018 June 30, 2017 December 31, 2017 December 31, 2016 (millions) Dominion Energy Cash and cash equivalents $ 190 $ 260 $ 120 $ 261 Restricted cash and equivalents (1) 164 64 65 61 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 354 $ 324 $ 185 $ 322 Virginia Power Cash and cash equivalents $ 20 $ 44 $ 14 $ 11 Restricted cash and equivalents (1) 10 — 10 — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 30 $ 44 $ 24 $ 11 Dominion Energy Gas Cash and cash equivalents $ 5 $ 4 $ 4 $ 23 Restricted cash and equivalents (1) 24 30 26 20 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 29 $ 34 $ 30 $ 43 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.
Investments	Distributions from Equity Method Investees Dominion Energy and Dominion Energy Gas each hold investments that are accounted for under the equity method of accounting. Effective January 2018, 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. Previously, distributions were determined to be either a return on an investment or return of an investment based on a cumulative earnings approach whereby any distributions received in excess of earnings were considered to be a return of an investment. Dominion Energy and Dominion Energy Gas have applied this approach on a retrospective basis. As a result, distributions from equity method investees were reclassified within Dominion Energy’s Consolidated Statement of Cash Flows between distributions from equity method affiliates to other adjustments from operating activities, which were previously reported as $(72) million for the six months ended June 30, 2017. There was no impact to Dominion Energy Gas for the six months ended June 30, 2017. Investments Debt and Equity Securities with Readily Determinable Fair Values Dominion Energy accounts for and classifies investments in debt securities as trading or available-for-sale securities. Virginia Power classifies investments in debt securities as available-for-sale securities. • Debt securities classified as trading securities include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income. • Debt securities classified as available-for-sale securities include all other debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power’s nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale debt securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax. In determining realized gains and losses for 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. Equity Securities without Readily Determinable Fair Values 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 when the Companies have the ability to exercise significant influence, but not control, over the investee. Dominion Energy’s investments are included in investments in equity method affiliates and Dominion Energy Gas’ investments are included in investments in their Consolidated Balance Sheets. Dominion Energy and Dominion Energy Gas record equity method adjustments in other income and earnings from equity method investee, respectively, in their Consolidated Statements of Income, including their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method. • Cost method investments when Dominion Energy and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion Energy’s and Virginia Power’s investments are included in other investments and nuclear decommissioning trust funds. Cost method investments are reported at cost less impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for identical or similar investments of the same issuer. Other-Than-Temporary Impairment 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 or 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 that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, Dominion Energy and Virginia Power record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.
New Accounting Standards	New Accounting Standards Revenue Recognition 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 recorded offsetting operating revenue and other energy-related purchases of $25 million and $50 million in the Consolidated Statements of Income for non-cash consideration for performing processing and fractionation services related to NGLs for the three and six months ended June 30, 2018, respectively. No such amounts were recorded during the three and six months ended June 30, 2017. Dominion Energy and Dominion Energy Gas no longer record offsetting operating revenue and purchased gas for fuel retained to offset costs on certain transportation and storage arrangements. Such amounts at Dominion Energy were $31 million and $63 million, respectively, and Dominion Energy Gas were $24 million and $48 million, respectively, recorded in the Consolidated Statements of Income for the three and six months ended June 30, 2017. Financial Instruments 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) and $119 million ($73 million after-tax), respectively, of net unrealized gains from AOCI to retained earnings. Dominion Energy and Virginia Power also recorded approximately $36 million ($22 million after-tax) in net unrealized gains on equity securities previously classified as cost method investments, of which $3 million was recorded to retained earnings and $33 million was recorded to regulatory liabilities for net unrealized gains subject to cost-based regulation. As a result of adopting this revised accounting guidance, Dominion Energy recorded unrealized gains on equity securities, net of regulatory deferrals, of $45 million ($36 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax) in other income in the Consolidated Statements of Income for the three and six months ended June 30, 2018, respectively, resulting in a $0.06 gain per share for the three months ended June 30, 2018. There was no impact to per share amounts at Dominion Energy for the six months ended June 30, 2018. Virginia Power recorded unrealized gains on equity securities, net of regulatory deferrals, of $6 million ($5 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax), respectively, in other income in the Consolidated Statements of Income for the three and six months ended June 30, 2018. Derecognition and Partial Sales of Nonfinancial Assets 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. Net Periodic Pension and Other Postretirement Benefit Costs In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic pension and other postretirement benefit costs. The update 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 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. This guidance became effective for the Companies beginning January 1, 2018 with a retrospective adoption for income statement presentation and a prospective adoption for capitalization. Dominion Energy’s and Dominion Energy Gas’ Consolidated Statements of Income for the six months ended June 30, 2017 have been recast to reflect retrospective adoption for the presentation of the non-service cost component of net periodic pension and other postretirement benefit costs. Previously, the non-service cost component for Dominion Energy and Dominion Energy Gas was reflected in other operations and maintenance in the Consolidated Statements of Income, along with the service cost component of net periodic pension and other postretirement benefit costs. Subsequent to the adoption of this guidance, the non-service cost component of net periodic pension and other postretirement benefit costs is recorded in other income in the Consolidated Statements of Income. As previously reported, Dominion Energy’s other operations and maintenance expense and other income for the three months ended June 30, 2017 were $779 million and $60 million, respectively, and were $1.5 billion and $176 million for the six months ended June 30, 2017, respectively. Dominion Energy Gas’ other operations and maintenance expense and other income for the three months ended June 30, 2017 were $126 million and $5 million, respectively, and were $259 million and $10 million for the six months ended June 30, 2017, respectively. Tax Reform 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	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, futures, and swaps contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards, futures, and swaps calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices, and volumes. For Level 3 fair value measurements, certain forward market prices and implied price volatilities are considered unobservable. The unobservable inputs are developed and substantiated using historical information, available market data, third-party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third-party pricing sources.
Regulatory Matters Involving Potential Loss Contingencies	As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations.
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 for which the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the Companies’ maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the 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.

Significant Accounting Polici30

Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
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 six months ended June 30, 2018 and 2017: Cash, Restricted Cash and Equivalents at End of Period Cash, Restricted Cash and Equivalents at Beginning of Period June 30, 2018 June 30, 2017 December 31, 2017 December 31, 2016 (millions) Dominion Energy Cash and cash equivalents $ 190 $ 260 $ 120 $ 261 Restricted cash and equivalents (1) 164 64 65 61 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 354 $ 324 $ 185 $ 322 Virginia Power Cash and cash equivalents $ 20 $ 44 $ 14 $ 11 Restricted cash and equivalents (1) 10 — 10 — Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 30 $ 44 $ 24 $ 11 Dominion Energy Gas Cash and cash equivalents $ 5 $ 4 $ 4 $ 23 Restricted cash and equivalents (1) 24 30 26 20 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 29 $ 34 $ 30 $ 43 (1) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.

Operating Revenue (Tables)

Operating Revenue (Tables)	6 Months Ended
	Jun. 30, 2018
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: Three Months Ended June 30, Six Months Ended June 30, 2017 2017 (millions) Dominion Energy Electric sales: Regulated $ 1,716 $ 3,482 Nonregulated 307 734 Gas sales: Regulated 151 599 Nonregulated 110 254 Gas transportation and storage 430 922 Other 99 206 Total operating revenue $ 2,813 $ 6,197 Virginia Power Regulated electric sales $ 1,716 $ 3,482 Other 31 96 Total operating revenue $ 1,747 $ 3,578 Dominion Energy Gas Gas sales: Regulated $ 15 $ 47 Nonregulated 8 10 Gas transportation and storage 342 738 Other 57 117 Total operating revenue $ 422 $ 912
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 June 30, 2018 2018 2019 2020 2021 2022 Thereafter Total (millions) Dominion Energy $ 851 $ 1,686 $ 1,578 $ 1,466 $ 1,335 $ 15,240 $ 22,156 Virginia Power 11 21 3 1 — — 36 Dominion Energy Gas 324 633 570 485 394 2,168 4,574
Subsequent To Adoption of Revised Guidance
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: Three Months Ended June 30, Six Months Ended June 30, 2018 2018 (millions) Dominion Energy Regulated electric sales: Residential $ 788 $ 1,605 Commercial 636 1,160 Industrial 121 228 Government and other retail 210 423 Wholesale 23 65 Nonregulated electric sales 282 700 Regulated gas sales: Residential 116 480 Commercial 34 137 Other 1 11 Nonregulated gas sales 9 97 Regulated gas transportation and storage: FERC-regulated 272 534 State-regulated 144 334 Nonregulated gas transportation and storage 124 124 Other regulated revenues 44 94 Other nonregulated revenues (1)(2) 141 277 Total operating revenue from contracts with customers 2,945 6,269 Other revenues 143 285 Total operating revenue $ 3,088 $ 6,554 Virginia Power Regulated electric sales: Residential $ 788 $ 1,605 Commercial 636 1,160 Industrial 121 228 Government and other retail 210 423 Wholesale 23 65 Other regulated revenues 33 65 Other nonregulated revenues (1) 18 31 Total operating revenue from contracts with customers $ 1,829 $ 3,577 Dominion Energy Gas Regulated gas sales: Residential $ 13 $ 42 Other 2 9 Nonregulated gas sales (1) 1 3 Regulated gas transportation and storage: FERC-regulated (1) 183 382 State-regulated (1) 139 319 NGL revenue (1)(2) 50 104 Management service revenue (1) 60 107 Other regulated revenues (1) 4 12 Other nonregulated revenues (1) 4 6 Total operating revenue from contracts with customers 456 984 Other revenues (1) 3 1 Total operating revenue $ 459 $ 985 (1) See Notes 10 and 18 for amounts attributable to related parties and affiliates. (2) Amounts above include $33 million and $21 million for the three months ended June 30, 2018, and $63 million and $47 million for the six months ended June 30, 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.

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
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 Six Months Ended June 30, 2018 2017 2018 2017 2018 2017 U.S. statutory rate 21.0 % 35.0 % 21.0 % 35.0 % 21.0 % 35.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 3.8 2.8 4.5 3.7 3.6 1.5 Investment tax credits (0.9 ) (5.5 ) (1.4 ) (0.8 ) — — Production tax credits (0.7 ) (0.8 ) (0.7 ) (0.5 ) — — Reversal of excess deferred income taxes (1.5 ) — (2.0 ) — (1.2 ) — State legislative change (1.6 ) — — — 0.3 — AFUDC - equity (1.0 ) (1.4 ) (0.5 ) (0.6 ) (0.4 ) (1.0 ) Other, net (1.0 ) (2.6 ) 0.3 (0.1 ) 0.2 — Effective tax rate 18.1 % 27.5 % 21.2 % 36.7 % 23.5 % 35.5 %

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share Computation	The following table presents the calculation of Dominion Energy’s basic and diluted EPS: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions, except EPS) Net income attributable to Dominion Energy $ 449 $ 390 $ 952 $ 1,022 Average shares of common stock outstanding – Basic 652.8 629.2 651.6 628.7 Net effect of dilutive securities 0.3 — 0.2 — Average shares of common stock outstanding – Diluted 653.1 629.2 651.8 628.7 Earnings Per Common Share – Basic $ 0.69 $ 0.62 $ 1.46 $ 1.63 Earnings Per Common Share – Diluted $ 0.69 $ 0.62 $ 1.46 $ 1.63

Accumulated Other Comprehensi34

Accumulated Other Comprehensive Income (Tables)	6 Months Ended
	Jun. 30, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Dominion Energy’s changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrealized gains and losses on investment securities Unrecognized pension and other postretirement benefit costs Other comprehensive loss from equity method investees Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (248 ) $ 3 $ (1,303 ) $ (3 ) $ (1,551 ) Other comprehensive income before reclassifications: gains (losses) (33 ) (5 ) — 1 (37 ) Amounts reclassified from AOCI: (gains) losses (1) 33 — 17 — 50 Net current period other comprehensive income (loss) — (5 ) 17 1 13 Ending balance $ (248 ) $ (2 ) $ (1,286 ) $ (2 ) $ (1,538 ) Three Months Ended June 30, 2017 Beginning balance $ (260 ) $ 599 $ (1,069 ) $ (5 ) $ (735 ) Other comprehensive income before reclassifications: gains (losses) 28 35 — 1 64 Amounts reclassified from AOCI: (gains) losses (1) (18 ) (4 ) 11 — (11 ) Net current period other comprehensive income (loss) 10 31 11 1 53 Ending balance $ (250 ) $ 630 $ (1,058 ) $ (4 ) $ (682 ) Six Months Ended June 30, 2018 Beginning balance $ (302 ) $ 747 $ (1,101 ) $ (3 ) $ (659 ) Other comprehensive income before reclassifications: gains (losses) 78 (18 ) — 1 61 Amounts reclassified from AOCI: (gains) losses (1) 41 1 42 — 84 Net current period other comprehensive income (loss) 119 (17 ) 42 1 145 Cumulative-effect of changes in accounting principle (64 ) (732 ) (227 ) — (1,023 ) Less other comprehensive income attributable to noncontrolling interest 1 — — — 1 Ending balance $ (248 ) $ (2 ) $ (1,286 ) $ (2 ) $ (1,538 ) Six Months Ended June 30, 2017 Beginning balance $ (280 ) $ 569 $ (1,082 ) $ (6 ) $ (799 ) Other comprehensive income before reclassifications: gains (losses) 71 93 — 2 166 Amounts reclassified from AOCI: (gains) losses (1) (41 ) (32 ) 24 — (49 ) Net current period other comprehensive income (loss) 30 61 24 2 117 Ending balance $ (250 ) $ 630 $ (1,058 ) $ (4 ) $ (682 ) (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 reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 16 Operating revenue Interest rate contracts 12 Interest and related charges Foreign currency contracts 16 Other income Total 44 Tax (11 ) Income tax expense Total, net of tax $ 33 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ 1 Other income Total 1 Tax (1 ) Income tax expense Total, net of tax $ — Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (5 ) Other income Amortization of actuarial losses 29 Other income Total 24 Tax (7 ) Income tax expense Total, net of tax $ 17 Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (19 ) Operating revenue (2 ) Electric fuel and other energy-related purchases Interest rate contracts 11 Interest and related charges Foreign currency contracts (19 ) Other income Total (29 ) Tax 11 Income tax expense Total, net of tax $ (18 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (11 ) Other income Impairment 5 Other income Total (6 ) Tax 2 Income tax expense Total, net of tax $ (4 ) Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (5 ) Other income Amortization of actuarial losses 26 Other income Total 21 Tax (10 ) Income tax expense Total, net of tax $ 11 Six Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 28 Operating revenue 2 Purchased gas (7 ) Electric fuel and other energy-related purchases Interest rate contracts 24 Interest and related charges Foreign currency contracts 8 Other income Total 55 Tax (14 ) Income tax expense Total, net of tax $ 41 Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ 2 Other income Total 2 Tax (1 ) Income tax expense Total, net of tax $ 1 Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (11 ) Other income Amortization of actuarial losses 61 Other income Total 50 Tax (8 ) Income tax expense Total, net of tax $ 42 Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (81 ) Operating revenue (2 ) Electric fuel and other energy-related purchases Interest rate contracts 23 Interest and related charges Foreign currency contracts (6 ) Other income Total (66 ) Tax 25 Income tax expense Total, net of tax $ (41 ) Unrealized (gains) and losses on investment securities: Realized (gain) loss on sale of securities $ (64 ) Other income Impairment 14 Other income Total (50 ) Tax 18 Income tax expense Total, net of tax $ (32 ) Unrecognized pension and other postretirement benefit costs: Amortization of prior-service costs (credits) $ (9 ) Other income Amortization of actuarial losses 51 Other income Total 42 Tax (18 ) Income tax expense Total, net of tax $ 24
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Virginia Power’s changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrealized gains and losses on investment securities Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (10 ) $ 1 $ (9 ) Other comprehensive income before reclassifications: gains (losses) 2 (2 ) — Amounts reclassified from AOCI: (gains) losses — — — Net current period other comprehensive income (loss) 2 (2 ) — Ending balance $ (8 ) $ (1 ) $ (9 ) Three Months Ended June 30, 2017 Beginning balance $ (8 ) $ 58 $ 50 Other comprehensive income before reclassifications: gains (losses) (3 ) 4 1 Amounts reclassified from AOCI: (gains) losses (1) 1 (1 ) — Net current period other comprehensive income (loss) (2 ) 3 1 Ending balance $ (10 ) $ 61 $ 51 Six Months Ended June 30, 2018 Beginning balance $ (12 ) $ 74 $ 62 Other comprehensive income before reclassifications: gains (losses) 7 (2 ) 5 Amounts reclassified from AOCI: (gains) losses — — — Net current period other comprehensive income (loss) 7 (2 ) 5 Cumulative-effect of changes in accounting principle (3 ) (73 ) (76 ) Ending balance $ (8 ) $ (1 ) $ (9 ) Six Months Ended June 30, 2017 Beginning balance $ (8 ) $ 54 $ 46 Other comprehensive income before reclassifications: gains (losses) (3 ) 11 8 Amounts reclassified from AOCI: (gains) losses (1) 1 (4 ) (3 ) Net current period other comprehensive income (loss) (2 ) 7 5 Ending balance $ (10 ) $ 61 $ 51 (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. Reclassifications out of AOCI were immaterial for the three and six months ended June 30, 2018. Details about AOCI components Amounts reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: 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 $ (1 ) Other income Total (1 ) Tax — Income tax expense Total, net of tax $ (1 ) Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: 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 $ (7 ) Other income Impairment 1 Other income Total (6 ) Tax 2 Income tax expense Total, net of tax $ (4 )
Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents Dominion Energy Gas’ changes in AOCI by component, net of tax: Deferred gains and losses on derivatives- hedging activities Unrecognized pension costs Total (millions) Three Months Ended June 30, 2018 Beginning balance $ (18 ) $ (95 ) $ (113 ) Other comprehensive income before reclassifications: gains (losses) (20 ) — (20 ) Amounts reclassified from AOCI: (gains) losses (1) 14 1 15 Net current period other comprehensive income (loss) (6 ) 1 (5 ) Ending balance $ (24 ) $ (94 ) $ (118 ) Three Months Ended June 30, 2017 Beginning balance $ (22 ) $ (99 ) $ (121 ) Other comprehensive income before reclassifications: gains (losses) 11 — 11 Amounts reclassified from AOCI: (gains) losses (1) (12 ) 2 (10 ) Net current period other comprehensive income (loss) (1 ) 2 1 Ending balance $ (23 ) $ (97 ) $ (120 ) Six Months Ended June 30, 2018 Beginning balance $ (23 ) $ (75 ) $ (98 ) Other comprehensive income before reclassifications: gains (losses) (7 ) — (7 ) Amounts reclassified from AOCI: (gains) losses (1) 11 2 13 Net current period other comprehensive income (loss) 4 2 6 Cumulative-effect of changes in accounting principle (5 ) (21 ) (26 ) Ending balance $ (24 ) $ (94 ) $ (118 ) Six Months Ended June 30, 2017 Beginning balance $ (24 ) $ (99 ) $ (123 ) Other comprehensive income before reclassifications: gains (losses) 2 — 2 Amounts reclassified from AOCI: (gains) losses (1) (1 ) 2 1 Net current period other comprehensive income (loss) 1 2 3 Ending balance $ (23 ) $ (97 ) $ (120 ) (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 reclassified from AOCI Affected line item in the Consolidated Statements of Income (millions) Three Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 2 Operating revenue Interest rate contracts 1 Interest and related charges Foreign currency contracts 16 Other income Total 19 Tax (5 ) Income tax expense Total, net of tax $ 14 Unrecognized pension costs: Actuarial losses $ 1 Other income Total 1 Tax — Income tax expense Total, net of tax $ 1 Three Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ (1 ) Operating revenue Interest rate contracts 1 Interest and related charges Foreign currency contracts (19 ) Other income Total (19 ) Tax 7 Income tax expense Total, net of tax $ (12 ) Unrecognized pension costs: Actuarial losses $ 2 Other income Total 2 Tax — Income tax expense Total, net of tax $ 2 Six Months Ended June 30, 2018 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 5 Operating revenue Interest rate contracts 2 Interest and related charges Foreign currency contracts 8 Other income Total 15 Tax (4 ) Income tax expense Total, net of tax $ 11 Unrecognized pension costs: Actuarial losses $ 3 Other income Total 3 Tax (1 ) Income tax expense Total, net of tax $ 2 Six Months Ended June 30, 2017 Deferred (gains) and losses on derivatives-hedging activities: Commodity contracts $ 3 Operating revenue Interest rate contracts 2 Interest and related charges Foreign currency contracts (6 ) Other income Total (1 ) Tax — Income tax expense Total, net of tax $ (1 ) Unrecognized pension costs: Actuarial losses $ 3 Other income Total 3 Tax (1 ) Income tax expense Total, net of tax $ 2

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Inputs, Assets, Quantitative Information	The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at June 30, 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 Average (1) Assets Physical and financial forwards and futures: Natural gas (2) $ 90 Discounted cash flow Market price (per Dth) (3) (1) - 6 — FTRs 7 Discounted cash flow Market price (per MWh) (3) (1) - 6 — Physical options: Natural gas 1 Option model Market price (per Dth) (3) 2 - 6 3 Price volatility (4) 13% - 35% 23 % Electricity 24 Option model Market price (per MWh) (3) 24 - 51 37 Price volatility (4) 4% - 62% 29 % Total assets $ 122 Liabilities Financial forwards: FTRs $ 3 Discounted cash flow Market price (per MWh) (3) (1) - 6 1 Total liabilities $ 3 (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 Value Measurement Market price Buy Increase (decrease) Gain (loss) Market price Sell Increase (decrease) Loss (gain) Price volatility Buy Increase (decrease) Gain (loss) Price volatility Sell Increase (decrease) Loss (gain)
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) At June 30, 2018 Assets Derivatives: Commodity $ — $ 37 $ 122 $ 159 Interest rate — 58 — 58 Foreign currency — 33 — 33 Investments (1) Equity securities: U.S. 3,529 — — 3,529 Fixed income securities: Corporate debt instruments — 445 — 445 Government securities 270 837 — 1,107 Cash equivalents and other 14 — — 14 Total assets $ 3,813 $ 1,410 $ 122 $ 5,345 Liabilities Derivatives: Commodity $ — $ 52 $ 3 $ 55 Interest rate — 58 — 58 Foreign currency — 5 — 5 Total liabilities $ — $ 115 $ 3 $ 118 At 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 securities: 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 $211 million and $88 million of assets at June 30, 2018 and December 31, 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: Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Beginning balance $ 120 $ 130 $ 150 $ 139 Total realized and unrealized gains (losses): Included in earnings (2 ) (10 ) (20 ) (25 ) Included in other comprehensive income — — 1 — Included in regulatory assets/liabilities 11 32 (10 ) 23 Settlements (10 ) — (3 ) 12 Transfers out of Level 3 — — 1 3 Ending balance $ 119 $ 152 $ 119 $ 152
Fair Value Unobservable Inputs Gain (Loss) Included In Earnings	The following table presents Dominion Energy’s classification of gains and losses included in earnings in the Level 3 fair value category. Operating Revenue Electric Fuel and Other Energy-Related Purchases Total (millions) Three Months Ended June 30, 2018 Total gains (losses) included in earnings $ — $ (2 ) $ (2 ) Three Months Ended June 30, 2017 Total gains (losses) included in earnings $ — $ (10 ) $ (10 ) Six Months Ended June 30, 2018 Total gains (losses) included in earnings $ (1 ) $ (19 ) $ (20 ) Six Months Ended June 30, 2017 Total gains (losses) included in earnings $ — $ (25 ) $ (25 )
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	For the Companies' financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows: June 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Energy Long-term debt, including securities due within one year (2) $ 29,629 $ 30,779 $ 28,666 $ 31,233 Junior subordinated notes (3) 3,981 4,016 3,981 4,102 Remarketable subordinated notes (3) 1,382 1,294 1,379 1,446 Credit facility borrowings 73 73 — — Virginia Power Long-term debt, including securities due within one year (3) $ 11,091 $ 11,799 $ 11,346 $ 12,842 Dominion Energy Gas Long-term debt, including securities due within one year (4) $ 4,062 $ 4,094 $ 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 issues with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value. (2) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At June 30, 2018 and December 31, 2017, includes the valuation of certain fair value hedges associated with fixed rate debt of $(61) 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 June 30, 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 Average (1) Assets Physical and financial forwards and futures: Natural gas (2) $ 86 Discounted cash flow Market price (per Dth) (3) (1) - 6 (1 ) FTRs 7 Discounted cash flow Market price (per MWh) (3) (1) - 6 — Physical options: Natural gas 1 Option model Market price (per Dth) (3) 2 - 6 3 Price volatility (4) 13% - 35% 23 % Electricity 24 Option model Market price (per MWh) (3) 24 - 51 37 Price volatility (4) 4% - 62% 29 % Total assets $ 118 Liabilities Financial forwards: FTRs $ 3 Discounted cash flow Market price (per MWh) (3) (1) - 6 1 Total liabilities $ 3 (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 Value Measurement Market price Buy Increase (decrease) Gain (loss) Market price Sell Increase (decrease) Loss (gain) Price volatility Buy Increase (decrease) Gain (loss) Price volatility Sell Increase (decrease) Loss (gain)
Fair Value, by Balance Sheet Grouping	The following table presents Virginia Power’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions: Level 1 Level 2 Level 3 Total (millions) At June 30, 2018 Assets Derivatives: Commodity $ — $ 8 $ 118 $ 126 Interest rate — 21 — 21 Investments (1) Equity securities: U.S. 1,584 — — 1,584 Fixed income securities: Corporate debt instruments — 227 — 227 Government securities 164 328 — 492 Cash equivalents and other 3 — — 3 Total assets $ 1,751 $ 584 $ 118 $ 2,453 Liabilities Derivatives: Commodity $ — $ 5 $ 3 $ 8 Interest rate — 6 — 6 Total liabilities $ — $ 11 $ 3 $ 14 At December 31, 2017 Assets Derivatives: Commodity $ — $ 14 $ 152 $ 166 Investments (1) Equity securities: U.S. 1,566 — — 1,566 Fixed income securities: 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 $171 million and $27 million of assets at June 30, 2018 and December 31, 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: Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Beginning balance $ 117 $ 132 $ 147 $ 143 Total realized and unrealized gains (losses): Included in earnings (2 ) (10 ) (19 ) (25 ) Included in regulatory assets/liabilities 8 31 (11 ) 23 Settlements (8 ) (1 ) (2 ) 11 Ending balance $ 115 $ 152 $ 115 $ 152
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) At June 30, 2018 Assets Interest rate $ — $ 1 $ — $ 1 Foreign currency — 33 — 33 Total assets $ — $ 34 $ — $ 34 Liabilities Commodity $ — $ 7 $ — $ 7 Interest rate — 4 — 4 Foreign currency — 5 — 5 Total liabilities $ — $ 16 $ — $ 16 At 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’ assets and liabilities for derivatives measured at fair value on a recurring basis and included in the Level 3 fair value category. There were no net changes in assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category for the three months ended June 30, 2018 and 2017. Six Months Ended June 30, 2018 2017 (millions) Beginning balance $ (2 ) $ (2 ) Total realized and unrealized gains (losses): Included in other comprehensive income (loss) 1 (1 ) Transfers out of Level 3 1 3 Ending balance $ — $ —

Derivatives and Hedge Account36

Derivatives and Hedge Accounting Activities (Tables)	6 Months Ended
	Jun. 30, 2018
Offsetting Assets	The tables below present Dominion Energy’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting: June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 130 $ — $ 130 $ 174 $ — $ 174 Exchange 21 — 21 80 — 80 Interest rate contracts: Over-the-counter 58 — 58 17 — 17 Foreign currency contracts: Over-the-counter 33 — 33 32 — 32 Total derivatives, subject to a master netting or similar arrangement 242 — 242 303 — 303 Total derivatives, not subject to a master netting or similar arrangement 8 — 8 4 — 4 Total $ 250 $ — $ 250 $ 307 $ — $ 307 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 130 $ 7 $ — $ 123 $ 174 $ 9 $ — $ 165 Exchange 21 21 — — 80 80 — — Interest rate contracts: Over-the-counter 58 9 — 49 17 8 — 9 Foreign currency contracts: Over-the-counter 33 5 — 28 32 2 — 30 Total $ 242 $ 42 $ — $ 200 $ 303 $ 99 $ — $ 204
Offsetting Liabilities	June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 23 $ — $ 23 $ 76 $ — $ 76 Exchange 32 — 32 120 — 120 Interest rate contracts: Over-the-counter 58 — 58 85 — 85 Foreign currency contracts: Over-the-counter 5 — 5 2 — 2 Total derivatives, subject to a master netting or similar arrangement 118 — 118 283 — 283 Total derivatives, not subject to a master netting or similar arrangement — — — 1 — 1 Total $ 118 $ — $ 118 $ 284 $ — $ 284 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 23 $ 7 $ — $ 16 $ 76 $ 9 $ 6 $ 61 Exchange 32 21 11 — 120 80 40 — Interest rate contracts: Over-the-counter 58 9 — 49 85 8 — 77 Foreign currency contracts: Over-the-counter 5 5 — — 2 2 — — Total $ 118 $ 42 $ 11 $ 65 $ 283 $ 99 $ 46 $ 138
Schedule of Volume of Derivative Activity	The following table presents the volume of Dominion Energy’s derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 75 24 Basis 214 600 Electricity (MWh): Fixed price (1) 10,566,074 677,760 FTRs 102,797,191 — Liquids (Gal) (2) 51,019,800 — Interest rate (3) $ 600,000,000 $ 5,433,632,652 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 June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Commodities: Gas $ — $ 1 37 months Electricity (9 ) (9 ) 18 months Other (5 ) (5 ) 9 months Interest rate (246 ) (9 ) 378 months Foreign currency 12 (4 ) 96 months Total $ (248 ) $ (26 )
Fair Value of Derivatives	The following table presents the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Current Assets Commodity $ 10 $ 67 $ 77 Interest rate 12 — 12 Total current derivative assets (1) 22 67 89 Noncurrent Assets Commodity 1 81 82 Interest rate 46 — 46 Foreign currency 33 — 33 Total noncurrent derivative assets (2) 80 81 161 Total derivative assets $ 102 $ 148 $ 250 LIABILITIES Current Liabilities Commodity $ 30 $ 22 $ 52 Interest rate 12 — 12 Foreign currency 5 — 5 Total current derivative liabilities (3) 47 22 69 Noncurrent Liabilities Commodity 2 1 3 Interest rate 46 — 46 Total noncurrent derivative liabilities (4) 48 1 49 Total derivative liabilities $ 95 $ 23 $ 118 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 in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Three Months Ended June 30, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (16 ) Total commodity $ (39 ) $ (16 ) $ — Interest rate (3) 9 (12 ) 25 Foreign currency (4) (14 ) (16 ) — Total $ (44 ) $ (44 ) $ 25 Three Months Ended June 30, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 19 Electric fuel and other energy-related purchases 2 Total commodity $ 44 $ 21 $ — Interest rate (3) (15 ) (11 ) (42 ) Foreign currency (4) 16 19 — Total $ 45 $ 29 $ (42 ) Six Months Ended June 30, 2018 Derivative type and location of gains (losses): Commodity: Operating revenue $ (28 ) Purchased gas (2 ) Electric fuel and other energy-related purchases 7 Total commodity $ 58 $ (23 ) $ — Interest rate (3) 47 (24 ) 93 Foreign currency (4) (1 ) (8 ) — Total $ 104 $ (55 ) $ 93 Six Months Ended June 30, 2017 Derivative type and location of gains (losses): Commodity: Operating revenue $ 81 Electric fuel and other energy-related purchases 2 Total commodity $ 131 $ 83 $ — Interest rate (3) (14 ) (23 ) (34 ) Foreign currency (4) (2 ) 6 — Total $ 115 $ 66 $ (34 ) (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 Income on Derivatives (1) Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (9 ) $ 10 $ (3 ) $ 14 Purchased gas 4 (8 ) 4 8 Electric fuel and other energy-related purchases (3 ) (8 ) (16 ) (32 ) Other operations & maintenance — (1 ) — (1 ) Total $ (8 ) $ (7 ) $ (15 ) $ (11 ) (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, before and after the effects of offsetting: June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 117 $ — $ 117 $ 155 $ — $ 155 Interest rate contracts: Over-the-counter 21 — 21 — — — Total derivatives, subject to a master netting or similar arrangement 138 — 138 155 — 155 Total derivatives, not subject to a master netting or similar arrangement 9 — 9 11 — 11 Total $ 147 $ — $ 147 $ 166 $ — $ 166 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 117 $ 3 $ — $ 114 $ 155 $ 4 $ — $ 151 Interest rate contracts: Over-the-counter 21 3 — 18 — — — — Total $ 138 $ 6 $ — $ 132 $ 155 $ 4 $ — $ 151
Offsetting Liabilities	June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 3 $ — $ 3 $ 4 $ — $ 4 Interest rate contracts: Over-the-counter 6 — 6 57 — 57 Total derivatives, subject to a master netting or similar arrangement 9 — 9 61 — 61 Total derivatives, not subject to a master netting or similar arrangement 5 — 5 5 — 5 Total $ 14 $ — $ 14 $ 66 $ — $ 66 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 3 $ 3 $ — $ — $ 4 $ 4 $ — $ — Interest rate contracts: Over-the-counter 6 3 — 3 57 — — 57 Total $ 9 $ 6 $ — $ 3 $ 61 $ 4 $ — $ 57
Schedule of Volume of Derivative Activity	The following table presents the volume of Virginia Power’s derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 27 4 Basis 112 514 Electricity (MWh): Fixed price (1) 1,061,191 — FTRs 101,284,984 — Interest rate (2) $ 600,000,000 $ 1,000,000,000 (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 June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (8 ) $ (1 ) 378 months Total $ (8 ) $ (1 )
Fair Value of Derivatives	The following table presents the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Current Assets Commodity $ — $ 49 $ 49 Interest rate 8 — 8 Total current derivative assets (1) 8 49 57 Noncurrent Assets Commodity — 77 77 Interest rate 13 — 13 Total noncurrent derivative assets (2) 13 77 90 Total derivative assets $ 21 $ 126 $ 147 LIABILITIES Current Liabilities Commodity $ — $ 8 $ 8 Interest rate 4 — 4 Total current derivative liabilities (3) 4 8 12 Noncurrent Liabilities Interest rate 2 — 2 Total noncurrent derivatives liabilities (4) 2 — 2 Total derivative liabilities $ 6 $ 8 $ 14 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 derivatives 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Three Months Ended June 30, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 2 $ — $ 25 Total $ 2 $ — $ 25 Three Months Ended June 30, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (5 ) $ (1 ) $ (42 ) Total $ (5 ) $ (1 ) $ (42 ) Six Months Ended June 30, 2018 Derivative type and location of gains (losses): Interest rate (3) $ 9 $ — $ 93 Total $ 9 $ — $ 93 Six Months Ended June 30, 2017 Derivative type and location of gains (losses): Interest rate (3) $ (5 ) $ (1 ) $ (34 ) Total $ (5 ) $ (1 ) $ (34 ) (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 in Income on Derivatives (1) Three Months Ended Six Months Ended June 30, June 30, 2018 2017 2018 2017 (millions) Derivative type and location of gains (losses): Commodity (2) $ (3 ) $ (7 ) $ (3 ) $ (24 ) Total $ (3 ) $ (7 ) $ (3 ) $ (24 ) (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, before and after the effects of offsetting. June 30, 2018 December 31, 2017 Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Assets Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (millions) Interest rate contracts: Over-the-counter $ 1 $ — $ 1 $ — $ — $ — Foreign currency contracts: Over-the-counter 33 — 33 32 — 32 Total derivatives, subject to a master netting or similar arrangement $ 34 $ — $ 34 $ 32 $ — $ 32 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts Net Amounts of Assets Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Received Net Amounts (millions) Interest rate contracts: Over-the-counter $ 1 $ 1 $ — $ — $ — $ — $ — $ — Foreign currency contracts: Over-the-counter 33 5 — 28 32 2 — 30 Total $ 34 $ 6 $ — $ 28 $ 32 $ 2 $ — $ 30
Offsetting Liabilities	June 30, 2018 December 31, 2017 Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Gross Amounts of Recognized Liabilities Gross Amounts Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet (millions) Commodity contracts: Over-the-counter $ 7 $ — $ 7 $ 6 $ — $ 6 Interest rate contracts: Over-the-counter 4 — 4 — — — Foreign currency contracts: Over-the-counter 5 — 5 2 — 2 Total derivatives, subject to a master netting or similar arrangement $ 16 $ — $ 16 $ 8 $ — $ 8 June 30, 2018 December 31, 2017 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Net Amounts of Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts Over-the-counter $ 7 $ — $ — $ 7 $ 6 $ — $ — $ 6 Interest rate contracts: Over-the-counter 4 1 — 3 — — — — Foreign currency contracts: Over-the-counter 5 5 — — 2 2 — — Total $ 16 $ 6 $ — $ 10 $ 8 $ 2 $ — $ 6
Schedule of Volume of Derivative Activity	The following table presents the volume of Dominion Energy Gas’ derivative activity at June 30, 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 its long and short positions. Current Noncurrent Natural Gas (bcf): Basis 1 — NGLs (Gal) 45,643,800 — Interest rate (1) $ — $ 1,050,000,000 Foreign currency (1)(2) $ — $ 280,000,000 (1) Maturity is 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 June 30, 2018: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Commodities: NGLs $ (5 ) $ (5 ) 9 months Interest rate (31 ) (4 ) 318 months Foreign currency 12 (4 ) 96 months Total $ (24 ) $ (13 )
Fair Value of Derivatives	The following tables present the fair values of Dominion Energy Gas’ derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value-Derivatives Under Hedge Accounting Fair Value-Derivatives Not Under Hedge Accounting Total Fair Value (millions) June 30, 2018 ASSETS Noncurrent Assets Interest rate $ 1 $ — $ 1 Foreign currency 33 — 33 Total noncurrent derivative assets (1) 34 — 34 Total derivative assets $ 34 $ — $ 34 LIABILITIES Current Liabilities Commodity $ 7 $ — $ 7 Interest rate 1 — 1 Foreign currency 5 — 5 Total current derivative liabilities (2) 13 — 13 Noncurrent Liabilities Interest rate 3 — 3 Total noncurrent derivative liabilities (3) 3 — 3 Total derivative liabilities $ 16 $ — $ 16 December 31, 2017 ASSETS Noncurrent Assets Foreign currency $ 32 $ — $ 32 Total noncurrent derivative assets (1) 32 — 32 Total derivative assets $ 32 $ — $ 32 LIABILITIES Current Liabilities Commodity $ 6 $ — $ 6 Foreign currency 2 — 2 Total current derivative liabilities (2) 8 — 8 Total derivative liabilities $ 8 $ — $ 8 (1) Noncurrent derivatives assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (2) Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets. (3) 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 table presents 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 relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) (1) Amount of Gain (Loss) Reclassified From AOCI to Income (millions) Three Months Ended June 30, 2018 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (2 ) Total commodity $ (10 ) $ (2 ) Interest rate (2) (3 ) (1 ) Foreign currency (3) (14 ) (16 ) Total $ (27 ) $ (19 ) Three Months Ended June 30, 2017 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ 1 Total commodity $ 2 $ 1 Interest rate (2) — (1 ) Foreign currency (3) 16 19 Total $ 18 $ 19 Six Months Ended June 30, 2018 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (5 ) Total commodity $ (6 ) $ (5 ) Interest rate (2) (3 ) (2 ) Foreign currency (3) (1 ) (8 ) Total $ (10 ) $ (15 ) Six Months Ended June 30, 2017 Derivative Type and Location of Gains (Losses): Commodity: Operating revenue $ (3 ) Total commodity $ 4 $ (3 ) Interest rate (2) — (2 ) Foreign currency (3) (1 ) 6 Total $ 3 $ 1 (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.

Investments (Tables)

Investments (Tables)	6 Months Ended
	Jun. 30, 2018
Available-For-Sale Securities	Dominion Energy’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Fair Value (millions) June 30, 2018 Equity securities: (1) U.S. $ 1,695 $ 1,896 $ (14 ) $ 3,577 Fixed income securities: (2) Corporate debt instruments 447 6 (8 ) 445 Government securities 1,058 16 (14 ) 1,060 Common/collective trust funds 72 — — 72 Cash equivalents and other (3) 5 — — 5 Total $ 3,277 $ 1,918 $ (36 ) (4) $ 5,159 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 purchases of securities of $3 million at June 30, 2018 and pending sales of securities of (4) The fair value of securities in an unrealized loss position was $900 million
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: (millions) Three Months Ended June 30, 2018 Six Months Ended June 30, 2018 Net gains recognized during the period $ 89 $ 24 Less: Net gains recognized during the period on securities sold during the period (16 ) (35 ) Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018 (1) $ 73 $ (11 ) (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 June 30, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 321 Due after one year through five years 327 Due after five years through ten years 353 Due after ten years 576 Total $ 1,577
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. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Proceeds from sales $ 425 $ 363 $ 844 $ 1,119 Realized gains (1) 36 23 72 117 Realized losses (1) 23 16 42 36 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.
Virginia Electric and Power Company
Available-For-Sale Securities	Virginia Power’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Fair Value (millions) June 30, 2018 Equity securities: (1) U.S. $ 837 $ 861 $ (7 ) $ 1,691 Fixed income securities: (2) Corporate debt instruments 228 3 (4 ) 227 Government securities 490 7 (5 ) 492 Common/collective trust funds 32 — — 32 Cash equivalents and other (3) 7 — — 7 Total $ 1,594 $ 871 $ (16 ) (4) $ 2,449 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 $5 million and (4) The fair value of securities in an unrealized loss position was $414 million
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: Three Months Ended June 30, 2018 Six Months Ended June 30, 2018 (millions) Net gains recognized during the period $ 44 $ 12 Less: Net gains recognized during the period on securities sold during the period (8 ) (23 ) Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018 (1) $ 36 $ (11 ) (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 June 30, 2018 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 49 Due after one year through five years 158 Due after five years through ten years 216 Due after ten years 328 Total $ 751
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. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Proceeds from sales $ 196 $ 168 $ 414 $ 498 Realized gains (1) 15 10 33 55 Realized losses (1) 7 8 12 18 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

Regulatory Assets and Liabili38

Regulatory Assets and Liabilities (Tables)	6 Months Ended
	Jun. 30, 2018
Regulatory Assets And Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory assets and liabilities include the following: June 30, 2018 December 31, 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred rate adjustment clause costs (2) 89 70 Deferred nuclear refueling outage costs (3) 76 54 Unrecovered gas costs (4) 3 38 Other 104 109 Regulatory assets-current 616 294 Unrecognized pension and other postretirement benefit costs (5) 1,296 1,336 Deferred rate adjustment clause costs (2) 372 401 PJM transmission rates (6) 237 222 Utility reform legislation (7) 174 147 Derivatives (8) 131 223 Other 185 151 Regulatory assets-noncurrent 2,395 2,480 Total regulatory assets $ 3,011 $ 2,774 Regulatory liabilities: Reserve for rate credits to electric utility customers (9) $ 200 $ — Provision for future cost of removal and AROs (10) 101 101 Other 123 92 Regulatory liabilities-current (11) 424 193 Income taxes refundable through future rates (12) 4,037 4,058 Provision for future cost of removal and AROs (10) 1,407 1,384 Nuclear decommissioning trust (13) 1,147 1,121 Cost-of-service impact of 2017 Tax Reform Act (14) 84 — Other 390 353 Regulatory liabilities-noncurrent 7,065 6,916 Total regulatory liabilities $ 7,489 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred nuclear refueling outage costs (3) 76 54 Deferred rate adjustment clause costs (2) 56 56 Other 76 72 Regulatory assets-current 552 205 Deferred rate adjustment clause costs (2) 296 312 PJM transmission rates (6) 237 222 Derivatives (8) 98 190 Other 98 86 Regulatory assets-noncurrent 729 810 Total regulatory assets $ 1,281 $ 1,015 Regulatory liabilities: Reserve for rate credits to customers (9) $ 200 $ — Provision for future cost of removal (10) 80 80 Other 25 47 Regulatory liabilities-current (11) 305 127 Income taxes refundable through future rates (12) 2,567 2,581 Nuclear decommissioning trust (13) 1,147 1,121 Provision for future cost of removal (10) 927 915 Cost-of-service impact of 2017 Tax Reform Act (14) 72 — Derivatives (8) 65 69 Other 99 74 Regulatory liabilities-noncurrent 4,877 4,760 Total regulatory liabilities $ 5,182 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 33 $ 14 Unrecovered gas costs (4) — 8 Other 2 4 Regulatory assets-current (15) 35 26 Unrecognized pension and other postretirement benefit costs (5) 251 258 Utility reform legislation (7) 174 147 Deferred rate adjustment clause costs (2) 76 89 Other 25 17 Regulatory assets-noncurrent (16) 526 511 Total regulatory assets $ 561 $ 537 Regulatory liabilities: Overrecovered gas costs (4) $ 18 $ — Provision for future cost of removal and AROs (10) 13 13 PIPP (17) 3 20 Other 14 5 Regulatory liabilities-current (11) 48 38 Income taxes refundable through future rates (12) 993 998 Provision for future cost of removal and AROs (10) 165 160 Cost-of-service impact of 2017 Tax Reform Act (14) 11 — Other 84 69 Regulatory liabilities-noncurrent 1,253 1,227 Total regulatory liabilities $ 1,301 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. (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 or refunded through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy's and Dominion Energy Gas' rate-regulated subsidiaries. (6) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) 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) 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. (10) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (11) Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets. (12) Amounts recorded to pass the effect of reduced income taxes 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. (13) 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. (14) 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. (15) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. (16) Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (17) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rate adjustment clause according to East Ohio tariff provisions.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities include the following: June 30, 2018 December 31, 2017 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred rate adjustment clause costs (2) 89 70 Deferred nuclear refueling outage costs (3) 76 54 Unrecovered gas costs (4) 3 38 Other 104 109 Regulatory assets-current 616 294 Unrecognized pension and other postretirement benefit costs (5) 1,296 1,336 Deferred rate adjustment clause costs (2) 372 401 PJM transmission rates (6) 237 222 Utility reform legislation (7) 174 147 Derivatives (8) 131 223 Other 185 151 Regulatory assets-noncurrent 2,395 2,480 Total regulatory assets $ 3,011 $ 2,774 Regulatory liabilities: Reserve for rate credits to electric utility customers (9) $ 200 $ — Provision for future cost of removal and AROs (10) 101 101 Other 123 92 Regulatory liabilities-current (11) 424 193 Income taxes refundable through future rates (12) 4,037 4,058 Provision for future cost of removal and AROs (10) 1,407 1,384 Nuclear decommissioning trust (13) 1,147 1,121 Cost-of-service impact of 2017 Tax Reform Act (14) 84 — Other 390 353 Regulatory liabilities-noncurrent 7,065 6,916 Total regulatory liabilities $ 7,489 $ 7,109 Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 344 $ 23 Deferred nuclear refueling outage costs (3) 76 54 Deferred rate adjustment clause costs (2) 56 56 Other 76 72 Regulatory assets-current 552 205 Deferred rate adjustment clause costs (2) 296 312 PJM transmission rates (6) 237 222 Derivatives (8) 98 190 Other 98 86 Regulatory assets-noncurrent 729 810 Total regulatory assets $ 1,281 $ 1,015 Regulatory liabilities: Reserve for rate credits to customers (9) $ 200 $ — Provision for future cost of removal (10) 80 80 Other 25 47 Regulatory liabilities-current (11) 305 127 Income taxes refundable through future rates (12) 2,567 2,581 Nuclear decommissioning trust (13) 1,147 1,121 Provision for future cost of removal (10) 927 915 Cost-of-service impact of 2017 Tax Reform Act (14) 72 — Derivatives (8) 65 69 Other 99 74 Regulatory liabilities-noncurrent 4,877 4,760 Total regulatory liabilities $ 5,182 $ 4,887 Dominion Energy Gas Regulatory assets: Deferred rate adjustment clause costs (2) $ 33 $ 14 Unrecovered gas costs (4) — 8 Other 2 4 Regulatory assets-current (15) 35 26 Unrecognized pension and other postretirement benefit costs (5) 251 258 Utility reform legislation (7) 174 147 Deferred rate adjustment clause costs (2) 76 89 Other 25 17 Regulatory assets-noncurrent (16) 526 511 Total regulatory assets $ 561 $ 537 Regulatory liabilities: Overrecovered gas costs (4) $ 18 $ — Provision for future cost of removal and AROs (10) 13 13 PIPP (17) 3 20 Other 14 5 Regulatory liabilities-current (11) 48 38 Income taxes refundable through future rates (12) 993 998 Provision for future cost of removal and AROs (10) 165 160 Cost-of-service impact of 2017 Tax Reform Act (14) 11 — Other 84 69 Regulatory liabilities-noncurrent 1,253 1,227 Total regulatory liabilities $ 1,301 $ 1,265 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations. (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 or refunded through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy's and Dominion Energy Gas' rate-regulated subsidiaries. (6) Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information. (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) 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) 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. (10) Rates charged to customers by the Companies’ regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement. (11) Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets. (12) Amounts recorded to pass the effect of reduced income taxes 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. (13) 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. (14) 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. (15) Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets. (16) Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets. (17) Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rate adjustment clause according to East Ohio tariff provisions.

Significant Financing Transac39

Significant Financing Transactions (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Instrument [Line Items]
Schedule of Line of Credit Facilities	In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. At June 30, 2018, Dominion Energy’s commercial paper and letters of credit outstanding, as well as its capacity available under the credit facility, were as follows: Facility Limit Outstanding Commercial Paper Outstanding Letters of Credit Facility Capacity Available (millions) Joint revolving credit facility (1) $ 6,000 $ 2,743 $ 72 $ 3,185 (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.
Virginia Electric and Power Company
Debt Instrument [Line Items]
Schedule of Line of Credit Facilities	At June 30, 2018, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Dominion Energy Gas and Questar Gas was as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) Joint revolving credit facility (1) $ 6,000 $ 1,158 $ 1 (1) 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 June 30, 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.
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Schedule of Line of Credit Facilities	At June 30, 2018, Dominion Energy Gas' share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Virginia Power and Questar Gas was as follows: Facility Limit (1) Outstanding Commercial Paper Outstanding Letters of Credit (millions) Joint revolving credit facility (1) $ 1,500 $ 188 $ — (1) 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

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2018
Commitments And Contingencies Disclosure [Abstract]
Schedule Of Subsidiary Guarantees	At June 30, 2018, Dominion Energy had issued the following subsidiary guarantees: Maximum Exposure (millions) Commodity transactions (1) $ 2,142 Nuclear obligations (2) 200 Cove Point (3) 1,900 Solar (4) 636 Other (5) 577 Total (6) $ 5,455 (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 workers’ 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 June 30, 2018, Dominion Energy's maximum remaining cumulative exposure under these equity funding agreements is $10 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $6 million. (6) Excludes Dominion Energy's guarantee for the construction of a new corporate office property as discussed in Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018.

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2018
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	Presented below are Virginia Power’s significant transactions with DES and other affiliates: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Commodity purchases from affiliates $ 139 $ 137 $ 537 $ 349 Services provided by affiliates (1) 112 112 232 224 Services provided to affiliates 5 7 11 12 (1) Includes capitalized expenditures of
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (millions) Sales of natural gas and transportation and storage services to affiliates $ 16 $ 18 $ 34 $ 36 Purchases of natural gas from affiliates (2 ) 1 1 — Services provided by related parties (1) 33 36 66 73 Services provided to related parties (2) 61 36 113 75 (1) Includes capitalized expenditures of $7 million and $12 million for the three months ended June 30, 2018 and 2017, respectively, and $17 million and $20 million for the six months ended June 30, 2018 and 2017, 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: June 30, 2018 December 31, 2017 (millions) Other receivables (1) $ 19 $ 12 Customer receivables from related parties — 1 Imbalances receivable from affiliates — 1 Imbalances payable to affiliates (2) 5 — Affiliated notes receivable (3) 18 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.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net Periodic Benefit Cost (Credit)	The components of Dominion Energy’s provision for net periodic benefit cost (credit) were as follows: Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 (millions) Three Months Ended June 30, Service cost $ 40 $ 34 $ 6 $ 6 Interest cost 84 87 14 14 Expected return on plan assets (168 ) (161 ) (35 ) (31 ) Amortization of prior service cost (credit) 1 1 (13 ) (13 ) Amortization of net actuarial loss 49 41 2 3 Net periodic benefit cost (credit) $ 6 $ 2 $ (26 ) $ (21 ) Six Months Ended June 30, Service cost $ 79 $ 69 $ 13 $ 13 Interest cost 168 173 28 30 Expected return on plan assets (333 ) (320 ) (71 ) (63 ) Amortization of prior service cost (credit) 1 1 (26 ) (25 ) Amortization of net actuarial loss 97 81 5 6 Settlements — 1 — — Net periodic benefit cost (credit) $ 12 $ 5 $ (51 ) $ (39 )
Dominion Energy Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net Periodic Benefit Cost (Credit)	The components of Dominion Energy Gas’ provision for net periodic benefit cost (credit) for employees represented by collective bargaining units were as follows: Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 (millions) Three Months Ended June 30, Service cost $ 5 $ 4 $ 1 $ 1 Interest cost 7 8 2 3 Expected return on plan assets (38 ) (36 ) (6 ) (6 ) Amortization of prior service credit — — (1 ) (1 ) Amortization of net actuarial loss 5 4 1 — Net periodic benefit credit $ (21 ) $ (20 ) $ (3 ) $ (3 ) Six Months Ended June 30, Service cost $ 9 $ 8 $ 2 $ 2 Interest cost 14 15 5 6 Expected return on plan assets (75 ) (71 ) (14 ) (12 ) Amortization of prior service credit — — (2 ) (1 ) Amortization of net actuarial loss 10 8 2 1 Net periodic benefit credit $ (42 ) $ (40 ) $ (7 ) $ (4 )

Operating Segments (Tables)

Operating Segments (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting Information [Line Items]
Segment Reporting Disclosure Other Information	A description of the operations included in the Companies’ primary operating segments is as follows: Primary Operating Segment Description of Operations Dominion Energy Virginia Power Dominion Energy Gas Power Delivery Regulated electric distribution X X Regulated electric transmission X X Power Generation Regulated electric fleet X X Merchant electric fleet X Gas Infrastructure Gas transmission and storage X X Gas distribution and storage X X Gas gathering and processing X X LNG terminalling and storage X Nonregulated retail energy marketing X
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Energy’s operations: Power Delivery Power Generation Gas Infrastructure Corporate and Other Adjustments/ Eliminations Consolidated Total (millions) Three Months Ended June 30, 2018 Total revenue from external customers $ 528 $ 1,635 $ 914 $ (3 ) $ 14 $ 3,088 Intersegment revenue 6 3 8 170 (187 ) — Total operating revenue 534 1,638 922 167 (173 ) 3,088 Net income (loss) attributable to Dominion Energy 145 276 249 (221 ) — 449 Three Months Ended June 30, 2017 Total revenue from external customers $ 530 $ 1,507 $ 589 $ 6 $ 181 $ 2,813 Intersegment revenue 7 2 175 149 (333 ) — Total operating revenue 537 1,509 764 155 (152 ) 2,813 Net income (loss) attributable to Dominion Energy 127 240 163 (140 ) — 390 Six Months Ended June 30, 2018 Total revenue from external customers $ 1,091 $ 3,495 $ 2,136 $ (210 ) $ 42 $ 6,554 Intersegment revenue 12 5 14 345 (376 ) — Total operating revenue 1,103 3,500 2,150 135 (334 ) 6,554 Net income (loss) attributable to Dominion Energy 301 624 576 (549 ) — 952 Six Months Ended June 30, 2017 Total revenue from external customers $ 1,084 $ 3,160 $ 1,490 $ 9 $ 454 $ 6,197 Intersegment revenue 12 5 441 301 (759 ) — Total operating revenue 1,096 3,165 1,931 310 (305 ) 6,197 Net income (loss) attributable to Dominion Energy 252 501 426 (157 ) — 1,022
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Virginia Power’s operations: Power Delivery Power Generation Corporate and Other Consolidated Total (millions) Three Months Ended June 30, 2018 Operating revenue $ 528 $ 1,301 $ — $ 1,829 Net income (loss) 145 227 (33 ) 339 Three Months Ended June 30, 2017 Operating revenue $ 533 $ 1,214 $ — $ 1,747 Net income (loss) 125 198 (5 ) 318 Six Months Ended June 30, 2018 Operating revenue $ 1,091 $ 2,701 $ (215 ) $ 3,577 Net income (loss) 299 449 (225 ) 523 Six Months Ended June 30, 2017 Operating revenue $ 1,090 $ 2,488 $ — $ 3,578 Net income 250 421 3 674
Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Energy Gas’ operations: Gas Infrastructure Corporate Other Consolidated Total (millions) Three Months Ended June 30, 2018 Operating revenue $ 459 $ — $ 459 Net income (loss) 108 (93 ) 15 Three Months Ended June 30, 2017 Operating revenue $ 422 $ — $ 422 Net income (loss) 88 (11 ) 77 Six Months Ended June 30, 2018 Operating revenue $ 985 $ — $ 985 Net income (loss) 275 (94 ) 181 Six Months Ended June 30, 2017 Operating revenue $ 912 $ — $ 912 Net income (loss) 197 (12 ) 185

Significant Accounting Polici44

Significant Accounting Policies (Narrative) (Detail) $ / shares in Units, $ in Millions		Jan. 03, 2018USD ($)	Jun. 30, 2018USD ($)$ / shares	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)Contract	Jun. 30, 2017USD ($)	Jan. 01, 2018USD ($)
Significant Accounting Policies [Line Items]
Payments for sales and services due period					1 month
Cash provided by (used in) other investing activities					$ (3)	$ (4)
Other adjustments					42	64
Decrease in depreciation expense			$ 30
Decrease in depreciation expense, after tax			23
Purchased gas			64	$ 112	404	417
Unrealized gains reclassified from AOCI to retained earnings			1,100		1,100
Unrealized gains reclassified from AOCI to retained earnings after-tax					734
Unrealized gain (loss) on securities recorded in other income, before tax	[1]		$ 73		(11)
Gain per share from unrealized loss on securities | $ / shares			$ 0.06
Other operations and maintenance			$ 1,007	827	1,803	1,611
Other income			185	108	285	270
Tax reform, reclassification of tax expense (benefit) from AOCI to retained earnings					(289)
Accounting Standards Update 2014-09 [Member] | Performing Processing And Fractionation Services
Significant Accounting Policies [Line Items]
Operating revenue			25	0	50	0
Other energy-related purchases			25	0	50	0
Accounting Standards Update 2014-09 [Member] | Transportation And Storage Arrangements
Significant Accounting Policies [Line Items]
Operating revenue				31		63
Purchased gas				31		63
Accounting Standards Update 2016-01 [Member]
Significant Accounting Policies [Line Items]
Unrealized gain (loss) on securities recorded in other income, before tax			45		(2)
Unrealized gain (loss) on securities recorded in other income, net of tax			36		(2)
Cumulative Effect Of Changes In Accounting Principle [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interest			3		3
Cumulative Effect Of Changes In Accounting Principle [Member] | Accounting Standards Update 2017-05 [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interest			$ 127		$ 127
Previously Reported
Significant Accounting Policies [Line Items]
Cash provided by (used in) other investing activities						4
Other adjustments						(72)
Other operations and maintenance				779		1,500
Other income				60		176
Merchant Solar Projects | Terra Nova Renewable Partners
Significant Accounting Policies [Line Items]
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%
Four Brothers and Three Cedars
Significant Accounting Policies [Line Items]
Percentage ownership in total units			50.00%		50.00%
Dominion Energy Midstream Partners, LP | Common Units
Significant Accounting Policies [Line Items]
Ownership interest percentage of limited partner interests					60.90%
Dominion Energy Midstream Partners, LP | Convertible Preferred Interests
Significant Accounting Policies [Line Items]
Ownership interest percentage of limited partner interests					37.50%
NRG Energy, Inc | Four Brothers and Three Cedars
Significant Accounting Policies [Line Items]
Percentage of equity interest sold to noncontrolling interest owners			33.00%		33.00%
Dominion Energy Gas Holdings, LLC
Significant Accounting Policies [Line Items]
Cash provided by (used in) other investing activities					$ (6)	(1)
Other adjustments					(4)	6
Purchased gas	[2]			38	29	81
Other income			$ 32	27	65	52
Tax reform, reclassification of tax expense (benefit) from AOCI to membership interests					(26)
Dominion Energy Gas Holdings, LLC | Accounting Standards Update 2014-09 [Member] | Performing Processing And Fractionation Services
Significant Accounting Policies [Line Items]
Operating revenue			25	0	50	0
Other energy-related purchases			25	0	50	0
Dominion Energy Gas Holdings, LLC | Accounting Standards Update 2014-09 [Member] | Transportation And Storage Arrangements
Significant Accounting Policies [Line Items]
Operating revenue				24		48
Purchased gas				24		48
Dominion Energy Gas Holdings, LLC | Cumulative Effect Of Changes In Accounting Principle [Member] | Accounting Standards Update 2014-09 [Member]
Significant Accounting Policies [Line Items]
Change in accounting principle to retained earnings and membership interest			3		3
Dominion Energy Gas Holdings, LLC | Previously Reported
Significant Accounting Policies [Line Items]
Cash provided by (used in) other investing activities						(11)
Other operations and maintenance				126		259
Other income				5		10
Virginia Electric and Power Company
Significant Accounting Policies [Line Items]
Cash provided by (used in) other investing activities					4	(17)
Other adjustments					19	20
Decrease in depreciation expense			46
Decrease in depreciation expense, after tax			36
Unrealized gains reclassified from AOCI to retained earnings							$ 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
Unrealized gain (loss) on securities recorded in other income, before tax	[1]		36		(11)
Other income			21	$ 13	24	44
Tax reform, reclassification of tax expense (benefit) from AOCI to membership interests					3
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 | 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 | Accounting Standards Update 2016-01 [Member]
Significant Accounting Policies [Line Items]
Unrealized gain (loss) on securities recorded in other income, before tax			6		(2)
Unrealized gain (loss) on securities recorded in other income, net of tax			$ 5		$ (2)
Virginia Electric and Power Company | Previously Reported
Significant Accounting Policies [Line Items]
Cash provided by (used in) other investing activities						$ 0
DETI | Cumulative Effect Of Changes In Accounting Principle [Member]
Significant Accounting Policies [Line Items]
Number of existing contracts | Contract					3
[1]	Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[2]	See Note 18 for amounts attributable to related parties.

Significant Accounting Polici45

Significant Accounting Policies (Reconciliation of Total Cash, Restricted Cash and Equivalents (Detail) - USD ($) $ in Millions		Jun. 30, 2018	Dec. 31, 2017		Jun. 30, 2017	Dec. 31, 2016
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents		$ 190	$ 120	[1]	$ 260	$ 261
Restricted cash and equivalents	[2]	164	65		64	61
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		354	185		324	322
Virginia Electric and Power Company
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents		20	14	[3]	44	11
Restricted cash and equivalents	[2]	10	10
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		30	24		44	11
Dominion Energy Gas Holdings, LLC
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents		5	4	[4]	4	23
Restricted cash and equivalents	[2]	24	26		30	20
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		$ 29	$ 30		$ 34	$ 43
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.
[3]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[4]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Acquisitions and Dispositions (

Acquisitions and Dispositions (Proposed Acquisition Of SCANA) (Narrative) (Detail) $ in Millions	1 Months Ended
	Jan. 31, 2018USD ($)
SCANA
Business Acquisition And Dispositions [Line Items]
Common stock agreed to issue	66.90%
One-time rate credit to electric service customers, period within closing	90 days
Business combination, refund to customers	$ 575
Discount on existing customers	7.00%
Period to recognize reduction to SCE&C electric service customers bills	8 years
Combination debt outstanding	$ 7,000
SCANA | Termination Fee Paid By Dominion to SCANA
Business Acquisition And Dispositions [Line Items]
Contract termination fee	280
SCANA | Termination Fee Paid to Dominion
Business Acquisition And Dispositions [Line Items]
Contract termination fee	240
SCANA | Upfront Payment | Electric Service Customers
Business Acquisition And Dispositions [Line Items]
Business combination, liability incurred	1,300
V C Summer Unit
Business Acquisition And Dispositions [Line Items]
Business combination cost related to exclusion from rate recovery	1,700
Columbia Energy
Business Acquisition And Dispositions [Line Items]
Business combination cost related to exclusion from rate recovery	$ 180

Acquisitions and Dispositions47

Acquisitions and Dispositions (Merchant Solar Projects) (Narrative) (Detail) $ in Millions

1 Months Ended

6 Months Ended

Dec. 31, 2017USD ($)MW

Nov. 30, 2017USD ($)MW

Oct. 31, 2017USD ($)

Sep. 30, 2017USD ($)

Jun. 30, 2017USD ($)projectMW

May 31, 2017USD ($)project

Apr. 30, 2017MW

Mar. 31, 2017USD ($)project

Feb. 28, 2017USD ($)

Aug. 31, 2016project

Jun. 30, 2018USD ($)MW

Jun. 30, 2017USD ($)

Jan. 31, 2017

Sep. 30, 2016

Business Acquisition And Dispositions [Line Items]

Cost of project

$ 51

$ 280

Solar Frontier Americas Holding, LLC

Business Acquisition And Dispositions [Line Items]

Percentage of equity interests acquired

100.00%

Number of projects | project

1

2

Cash consideration

$ 77

Cost of project

$ 78

MW capacity | MW

30

Discontinued efforts on acquisition of additional MW capacity | MW

20

Community Energy Solar, LLC

Business Acquisition And Dispositions [Line Items]

Percentage of equity interests acquired

100.00%

Cash consideration

$ 29

Cost of project

$ 205

MW capacity | MW

100

Solar Projects from Cypress Creek Renewables, LLC

Business Acquisition And Dispositions [Line Items]

Percentage of equity interests acquired

100.00%

Cash consideration

$ 154

Cost of project

$ 160

MW capacity | MW

79

Solar Projects from Hecate Energy Virginia C&C LLC

Business Acquisition And Dispositions [Line Items]

Percentage of equity interests acquired

100.00%

Number of projects | project

1

2

Cash consideration

$ 40

$ 16

$ 56

Cost of project

$ 57

MW capacity | MW

30

Solar Projects from Strata Solar Development, LLC and Moorings Farm 2 Holdco, LLC

Business Acquisition And Dispositions [Line Items]

Percentage of equity interests acquired

100.00%

100.00%

Cost of project

$ 41

MW capacity | MW

20

Four Solar Projects from Strata Solar Development, LLC and Moorings Farm 2 Holdco, LLC

Business Acquisition And Dispositions [Line Items]

Number of projects | project

4

Cash consideration

$ 40

Two Solar Projects from Strata Solar Development, LLC and Moorings Farm 2 Holdco, LLC

Business Acquisition And Dispositions [Line Items]

Number of projects | project

2

Cash consideration

$ 20

$ 20

Operating Revenue (Schedule of

Operating Revenue (Schedule of Operating Revenue Recognition from Contracts with Customers) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Public Utilities General Disclosures [Line Items]
Operating Revenue	[1]	$ 3,088	$ 2,813	$ 6,554	$ 6,197
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Operating Revenue	[2]	1,829	1,747	3,577	3,578
Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Operating Revenue	[3]	459	$ 422	985	$ 912
Subsequent To Adoption of Revised Guidance
Public Utilities General Disclosures [Line Items]
Operating revenue		2,945		6,269
Nonregulated electric sales		282		700
Nonregulated gas sales		9		97
Nonregulated gas transportation and storage		124		124
Other regulated revenues		44		94
Other nonregulated revenues	[4],[5]	141		277
Operating Revenue		3,088		6,554
Subsequent To Adoption of Revised Guidance | FERC-regulated
Public Utilities General Disclosures [Line Items]
Regulated gas transportation and storage		272		534
Subsequent To Adoption of Revised Guidance | State-regulated
Public Utilities General Disclosures [Line Items]
Regulated gas transportation and storage		144		334
Subsequent To Adoption of Revised Guidance | Residential
Public Utilities General Disclosures [Line Items]
Regulated gas sales		116		480
Subsequent To Adoption of Revised Guidance | Commercial
Public Utilities General Disclosures [Line Items]
Regulated gas sales		34		137
Subsequent To Adoption of Revised Guidance | Other
Public Utilities General Disclosures [Line Items]
Regulated gas sales		1		11
Subsequent To Adoption of Revised Guidance | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Operating revenue		1,829		3,577
Other regulated revenues		33		65
Other nonregulated revenues	[5]	18		31
Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Operating revenue		456		984
Nonregulated gas sales	[5]	1		3
Other regulated revenues	[5]	4		12
Other nonregulated revenues	[5]	4		6
Operating Revenue		459		985
Management service revenue	[5]	60		107
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]	183		382
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]	139		319
Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | Residential
Public Utilities General Disclosures [Line Items]
Regulated gas sales		13		42
Subsequent To Adoption of Revised Guidance | Dominion Energy Gas Holdings, LLC | Other
Public Utilities General Disclosures [Line Items]
Regulated gas sales		2		9
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Residential
Public Utilities General Disclosures [Line Items]
Operating revenue		788		1,605
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Commercial
Public Utilities General Disclosures [Line Items]
Operating revenue		636		1,160
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Industrial
Public Utilities General Disclosures [Line Items]
Operating revenue		121		228
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Government and Other Retail
Public Utilities General Disclosures [Line Items]
Operating revenue		210		423
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Wholesale
Public Utilities General Disclosures [Line Items]
Operating revenue		23		65
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Virginia Electric and Power Company | Residential
Public Utilities General Disclosures [Line Items]
Operating revenue		788		1,605
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Virginia Electric and Power Company | Commercial
Public Utilities General Disclosures [Line Items]
Operating revenue		636		1,160
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Virginia Electric and Power Company | Industrial
Public Utilities General Disclosures [Line Items]
Operating revenue		121		228
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Virginia Electric and Power Company | Government and Other Retail
Public Utilities General Disclosures [Line Items]
Operating revenue		210		423
Subsequent To Adoption of Revised Guidance | Regulated Electric Sales | Virginia Electric and Power Company | Wholesale
Public Utilities General Disclosures [Line Items]
Operating revenue		23		65
Subsequent To Adoption of Revised Guidance | Other Revenues
Public Utilities General Disclosures [Line Items]
Operating revenue		143		285
Subsequent To Adoption of Revised Guidance | Other Revenues | Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Operating revenue	[5]	3		1
Subsequent To Adoption of Revised Guidance | NGL Production | Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Operating revenue	[4],[5]	$ 50		$ 104
[1]	See Note 10 for amounts attributable to related parties.
[2]	See Note 18 for amounts attributable to affiliates.
[3]	See Note 18 for amounts attributable to related parties.
[4]	Amounts above include $33 million and $21 million for the three months ended June 30, 2018, and $63 million and $47 million for the six months ended June 30, 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.
[5]	See Notes 10 and 18 for amounts attributable to related parties and affiliates.

Operating Revenue (Schedule o49

Operating Revenue (Schedule of Operating Revenue Recognition from Contracts with Customers) (Parenthetical) (Detail) - NGL Midstream - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018
Public Utilities General Disclosures [Line Items]
NGL sales	$ 33	$ 63
Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
NGL sales	$ 21	$ 47

Operating Revenue (Schedule o50

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	Jun. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2018-07-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 851
Revenue, expected to be recognized on multi-year contracts, period	6 months
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	$ 1,686
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	$ 1,578
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	$ 1,466
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	$ 1,335
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	$ 15,240
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil)
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	22,156
Virginia Electric and Power Company | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2018-07-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 11
Revenue, expected to be recognized on multi-year contracts, period	6 months
Virginia Electric and Power Company | 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	$ 21
Revenue, expected to be recognized on multi-year contracts, period	1 year
Virginia Electric and Power Company | 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	$ 3
Revenue, expected to be recognized on multi-year contracts, period	1 year
Virginia Electric and Power Company | 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
Revenue, expected to be recognized on multi-year contracts, period	1 year
Virginia Electric and Power Company | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil)
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 36
Dominion Energy Gas Holdings, LLC | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2018-07-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 324
Revenue, expected to be recognized on multi-year contracts, period	6 months
Dominion Energy Gas Holdings, LLC | 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	$ 633
Revenue, expected to be recognized on multi-year contracts, period	1 year
Dominion Energy Gas Holdings, LLC | 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	$ 570
Revenue, expected to be recognized on multi-year contracts, period	1 year
Dominion Energy Gas Holdings, LLC | 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	$ 485
Revenue, expected to be recognized on multi-year contracts, period	1 year
Dominion Energy Gas Holdings, LLC | 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	$ 394
Revenue, expected to be recognized on multi-year contracts, period	1 year
Dominion Energy Gas Holdings, LLC | 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	$ 2,168
Dominion Energy Gas Holdings, LLC | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: (nil)
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 4,574

Operating Revenue (Narrative) (

Operating Revenue (Narrative) (Detail) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Revenues From Contract With Customer [Line Items]
Contract asset balances	$ 46	$ 46
Contract liability balances	71	132
Revenue recognized from contract liability balances	88
Dominion Energy Gas Holdings, LLC
Revenues From Contract With Customer [Line Items]
Contract asset balances	64	66
Contract liability balances	14	41
Revenue recognized from contract liability balances	40
Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Contract liability balances	25	$ 50
Revenue recognized from contract liability balances	$ 21

Operating Revenue (Schedule o52

Operating Revenue (Schedule of Operating Revenue For Revised Guidance of Revenue Recognition From Contracts with Customers ) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Public Utilities General Disclosures [Line Items]
Total operating revenue	[1]	$ 3,088	$ 2,813	$ 6,554	$ 6,197
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total operating revenue	[2]	1,829	1,747	3,577	3,578
Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Total operating revenue	[3]	$ 459	422	$ 985	912
Prior to adoption of revised guidance
Public Utilities General Disclosures [Line Items]
Nonregulated			307		734
Regulated			151		599
Nonregulated			110		254
Total operating revenue			2,813		6,197
Prior to adoption of revised guidance | Regulated Electric Sales
Public Utilities General Disclosures [Line Items]
Revenue			1,716		3,482
Prior to adoption of revised guidance | Gas Transportation and Storage
Public Utilities General Disclosures [Line Items]
Revenue			430		922
Prior to adoption of revised guidance | Other
Public Utilities General Disclosures [Line Items]
Revenue			99		206
Prior to adoption of revised guidance | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total operating revenue			1,747		3,578
Prior to adoption of revised guidance | Virginia Electric and Power Company | Regulated Electric Sales
Public Utilities General Disclosures [Line Items]
Revenue			1,716		3,482
Prior to adoption of revised guidance | Virginia Electric and Power Company | Other
Public Utilities General Disclosures [Line Items]
Revenue			31		96
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC
Public Utilities General Disclosures [Line Items]
Regulated			15		47
Nonregulated			8		10
Total operating revenue			422		912
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC | Gas Transportation and Storage
Public Utilities General Disclosures [Line Items]
Revenue			342		738
Prior to adoption of revised guidance | Dominion Energy Gas Holdings, LLC | Other
Public Utilities General Disclosures [Line Items]
Revenue			$ 57		$ 117
[1]	See Note 10 for amounts attributable to related parties.
[2]	See Note 18 for amounts attributable to affiliates.
[3]	See Note 18 for amounts attributable to related parties.

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Income Taxes at the U.S. Statutory Federal Income Tax Rate) (Detail)	6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
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	3.80%	2.80%
Investment tax credits	(0.90%)	(5.50%)
Production tax credits	(0.70%)	(0.80%)
Reversal of excess deferred income taxes	(1.50%)
State legislative change	(1.60%)
AFUDC - equity	(1.00%)	(1.40%)
Other, net	(1.00%)	(2.60%)
Effective tax rate	18.10%	27.50%
Virginia Electric and Power Company
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.50%	3.70%
Investment tax credits	(1.40%)	(0.80%)
Production tax credits	(0.70%)	(0.50%)
Reversal of excess deferred income taxes	(2.00%)
AFUDC - equity	(0.50%)	(0.60%)
Other, net	0.30%	(0.10%)
Effective tax rate	21.20%	36.70%
Dominion Energy Gas Holdings, LLC
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.60%	1.50%
Reversal of excess deferred income taxes	(1.20%)
State legislative change	0.30%
AFUDC - equity	(0.40%)	(1.00%)
Other, net	0.20%
Effective tax rate	23.50%	35.50%

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Detail)	6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Federal statutory income tax rate	21.00%	35.00%	35.00%
Percentage of deductibility of interest expense	30.00%

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		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Earnings Per Share [Abstract]
Net income attributable to Dominion Energy	$ 449	$ 390	$ 952	$ 1,022
Average shares of common stock outstanding – Basic	652.8	629.2	651.6	628.7
Net effect of dilutive securities	0.3		0.2
Average shares of common stock outstanding – Diluted	653.1	629.2	651.8	628.7
Earnings Per Common Share – Basic	$ 0.69	$ 0.62	$ 1.46	$ 1.63
Earnings Per Common Share – Diluted	$ 0.69	$ 0.62	$ 1.46	$ 1.63

Accumulated Other Comprehensi56

Accumulated Other Comprehensive Income (Schedule of Changes in AOCI by Component Net of Tax) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	[1]			$ 17,142
Total other comprehensive income (loss)		$ 13	$ 53	145	$ 117
Cumulative-effect of changes in accounting principles				6
Ending balance		18,064		18,064
Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance	[2]			12,224
Total other comprehensive income (loss)			1	5	5
Cumulative-effect of changes in accounting principles				3
Ending balance		12,497		12,497
Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total other comprehensive income (loss)		(5)	1	6	3
Cumulative-effect of changes in accounting principles				3
Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(248)	(260)	(302)	(280)
Other comprehensive income before reclassifications: gains (losses)		(33)	28	78	71
Amounts reclassified from AOCI: (gains) losses	[3]	33	(18)	41	(41)
Net current period other comprehensive income (loss)			10	119	30
Cumulative-effect of changes in accounting principles				(64)
Less other comprehensive income attributable to noncontrolling interest				1
Ending balance		(248)	(250)	(248)	(250)
Deferred Gains and Losses on Derivatives-Hedging Activities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(10)	(8)	(12)	(8)
Other comprehensive income before reclassifications: gains (losses)		2	(3)	7	(3)
Amounts reclassified from AOCI: (gains) losses	[3]		1		1
Total other comprehensive income (loss)		2	(2)	7	(2)
Cumulative-effect of changes in accounting principles				(3)
Ending balance		(8)	(10)	(8)	(10)
Deferred Gains and Losses on Derivatives-Hedging Activities | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(18)	(22)	(23)	(24)
Other comprehensive income before reclassifications: gains (losses)		(20)	11	(7)	2
Amounts reclassified from AOCI: (gains) losses	[3]	14	(12)	11	(1)
Total other comprehensive income (loss)		(6)	(1)	4	1
Cumulative-effect of changes in accounting principles				(5)
Ending balance		(24)	(23)	(24)	(23)
Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		3	599	747	569
Other comprehensive income before reclassifications: gains (losses)		(5)	35	(18)	93
Amounts reclassified from AOCI: (gains) losses	[3]		(4)	1	(32)
Net current period other comprehensive income (loss)		(5)	31	(17)	61
Cumulative-effect of changes in accounting principles				(732)
Ending balance		(2)	630	(2)	630
Unrealized Gains and Losses on Investment Securities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		1	58	74	54
Other comprehensive income before reclassifications: gains (losses)		(2)	4	(2)	11
Amounts reclassified from AOCI: (gains) losses	[3]		(1)		(4)
Total other comprehensive income (loss)		(2)	3	(2)	7
Cumulative-effect of changes in accounting principles				(73)
Ending balance		(1)	61	(1)	61
Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(1,303)	(1,069)	(1,101)	(1,082)
Amounts reclassified from AOCI: (gains) losses	[3]	17	11	42	24
Net current period other comprehensive income (loss)		17	11	42	24
Cumulative-effect of changes in accounting principles				(227)
Ending balance		(1,286)	(1,058)	(1,286)	(1,058)
Unrecognized Pension and Other Postretirement Benefit Costs | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(95)	(99)	(75)	(99)
Other comprehensive income before reclassifications: gains (losses)		0	0	0	0
Amounts reclassified from AOCI: (gains) losses	[3]	1	2	2	2
Total other comprehensive income (loss)		1	2	2	2
Cumulative-effect of changes in accounting principles				(21)
Ending balance		(94)	(97)	(94)	(97)
Other Comprehensive Loss From Equity Method Investee
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(3)	(5)	(3)	(6)
Other comprehensive income before reclassifications: gains (losses)		1	1	1	2
Net current period other comprehensive income (loss)		1	1	1	2
Ending balance		(2)	(4)	(2)	(4)
Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(1,551)	(735)	(659)	(799)
Other comprehensive income before reclassifications: gains (losses)		(37)	64	61	166
Amounts reclassified from AOCI: (gains) losses	[3]	50	(11)	84	(49)
Total other comprehensive income (loss)				144	117
Net current period other comprehensive income (loss)		13	53	145	117
Cumulative-effect of changes in accounting principles				(1,023)
Less other comprehensive income attributable to noncontrolling interest				1
Ending balance		(1,538)	(682)	(1,538)	(682)
Accumulated Other Comprehensive Income (Loss) | Virginia Electric and Power Company
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(9)	50	62	46
Other comprehensive income before reclassifications: gains (losses)			1	5	8
Amounts reclassified from AOCI: (gains) losses	[3]				(3)
Total other comprehensive income (loss)			1	5	5
Cumulative-effect of changes in accounting principles				(76)
Ending balance		(9)	51	(9)	51
Accumulated Other Comprehensive Income (Loss) | Dominion Energy Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance		(113)	(121)	(98)	(123)
Other comprehensive income before reclassifications: gains (losses)		(20)	11	(7)	2
Amounts reclassified from AOCI: (gains) losses	[3]	15	(10)	13	1
Total other comprehensive income (loss)		(5)	1	6	3
Cumulative-effect of changes in accounting principles				(26)
Ending balance		$ (118)	$ (120)	$ (118)	$ (120)
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	See table below for details about these reclassifications.

Accumulated Other Comprehensi57

Accumulated Other Comprehensive Income (Schedule of Reclassifications out of AOCI by Component Net of Tax) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Operating revenue	[1]	$ (3,088)	$ (2,813)	$ (6,554)	$ (6,197)
Interest and related charges		361	308	675	600
Other income		(185)	(108)	(285)	(270)
Income from operations including noncontrolling interests before income tax expense		(566)	(553)	(1,227)	(1,502)
Income tax expense		88	136	223	411
Purchased gas		64	112	404	417
Income tax expense		(11)	11	(14)	25
Income from continuing operations net of tax	[2]	33	(18)	41	(41)
Income tax expense		(1)	2	(1)	18
Income from continuing operations net of tax	[3]		(4)	1	(32)
Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Operating revenue	[4]	(1,829)	(1,747)	(3,577)	(3,578)
Interest and related charges	[4]	126	125	258	245
Other income		(21)	(13)	(24)	(44)
Income from operations including noncontrolling interests before income tax expense		(428)	(501)	(663)	(1,065)
Income tax expense		89	183	140	391
Income from continuing operations net of tax	[5]		1		1
Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Operating revenue	[6]	(459)	(422)	(985)	(912)
Interest and related charges	[6]	26	24	51	47
Other income		(32)	(27)	(65)	(52)
Income from operations including noncontrolling interests before income tax expense		(18)	(122)	(236)	(287)
Income tax expense		3	45	55	102
Purchased gas	[6]		38	29	81
Income tax expense		(5)	7	(4)
Income from continuing operations net of tax	[7]	14	(12)	11	(1)
Electric Fuel and Other Energy-Related Purchases
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Electric fuel and other energy-related purchases		623	498	1,367	1,073
Electric Fuel and Other Energy-Related Purchases | Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Electric fuel and other energy-related purchases	[4]	508	409	1,099	865
Deferred (gains) and losses on derivatives-hedging activities: | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Income from operations including noncontrolling interests before income tax expense		44	(29)	55	(66)
Income tax expense		(11)	11	(14)	25
Income from continuing operations including noncontrolling interests		33	(18)	41	(41)
Deferred (gains) and losses on derivatives-hedging activities: | Amounts Reclassified From AOCI | Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Income from operations before income tax expense			1		1
Income from continuing operations net of tax			1		1
Deferred (gains) and losses on derivatives-hedging activities: | Amounts Reclassified From AOCI | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Income from operations including noncontrolling interests before income tax expense		19	(19)	15	(1)
Income tax expense		(5)	7	(4)
Income from continuing operations including noncontrolling interests		14	(12)	11	(1)
Deferred (gains) and losses on derivatives-hedging activities: | Commodity contracts | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Operating revenue		16	(19)	28	(81)
Purchased gas				2
Deferred (gains) and losses on derivatives-hedging activities: | Commodity contracts | Amounts Reclassified From AOCI | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Operating revenue		2	(1)	5	3
Deferred (gains) and losses on derivatives-hedging activities: | Commodity contracts | Amounts Reclassified From AOCI | Electric Fuel and Other Energy-Related Purchases
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Electric fuel and other energy-related purchases			(2)	(7)	(2)
Deferred (gains) and losses on derivatives-hedging activities: | Interest rate contracts | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Interest and related charges		12	11	24	23
Deferred (gains) and losses on derivatives-hedging activities: | Interest rate contracts | Amounts Reclassified From AOCI | Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Interest and related charges			1		1
Deferred (gains) and losses on derivatives-hedging activities: | Interest rate contracts | Amounts Reclassified From AOCI | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Interest and related charges		1	1	2	2
Deferred (gains) and losses on derivatives-hedging activities: | Foreign currency | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income		16	(19)	8	(6)
Deferred (gains) and losses on derivatives-hedging activities: | Foreign currency | Amounts Reclassified From AOCI | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income		16	(19)	8	(6)
Unrealized (gains) and losses on investment securities: | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Realized (gain) loss on sale of securities		1	(11)	2	(64)
Impairment			5		14
Income from operations including noncontrolling interests before income tax expense		1	(6)	2	(50)
Income tax expense		(1)	2	(1)	18
Income from continuing operations including noncontrolling interests			(4)	1	(32)
Unrealized (gains) and losses on investment securities: | Amounts Reclassified From AOCI | Virginia Electric and Power Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Realized (gain) loss on sale of securities			(1)		(7)
Impairment					1
Income from operations before income tax expense			(1)		(6)
Income tax expense					2
Income from continuing operations net of tax			(1)		(4)
Amortization of prior-service costs (credits) | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income		(5)	(5)	(11)	(9)
Unrecognized pension and other postretirement benefit costs:
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		24	21	50	42
Unrecognized pension and other postretirement benefit costs, income tax expense		(7)	(10)	(8)	(18)
Unrecognized pension and other postretirement benefit costs, net of tax		17	11	42	24
Unrecognized pension and other postretirement benefit costs: | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		1	2	3	3
Unrecognized pension and other postretirement benefit costs, income tax expense				(1)	(1)
Unrecognized pension and other postretirement benefit costs, net of tax		1	2	2	2
Amortization of actuarial losses | Amounts Reclassified From AOCI
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income		29	26	61	51
Amortization of actuarial losses | Amounts Reclassified From AOCI | Dominion Energy Gas Holdings, LLC
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other income		$ 1	$ 2	$ 3	$ 3
[1]	See Note 10 for amounts attributable to related parties.
[2]	Net of $(11) million and $11 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(14) million and $25 million tax for the six months ended June 30, 2018 and 2017, respectively.
[3]	Net of $(1) million and $2 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million and $18 million tax for the six months ended June 30, 2018 and 2017, respectively.
[4]	See Note 18 for amounts attributable to affiliates.
[5]	Net of $— million tax for both the three and six months ended June 30, 2018 and 2017.
[6]	See Note 18 for amounts attributable to related parties.
[7]	Net of $(5) million and $7 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(4) million and $— million tax for the six months ended June 30, 2018 and 2017, respectively.

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Detail) $ in Millions		6 Months Ended
		Jun. 30, 2018USD ($)$ / MMBTU$ / MWh		Dec. 31, 2017USD ($)
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 250		$ 307
Fair Value of Derivative Liabilities		118		284
Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		147	[1]	166
Fair Value of Derivative Liabilities		14		66
Fair Value, Measurements, Recurring
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets	[2]	5,345		5,379
Total liabilities		118		284
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		2,453		2,466
Total liabilities		14		66
Fair Value, Measurements, Recurring | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		159		258
Fair Value of Derivative Liabilities		55		197
Fair Value, Measurements, Recurring | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		126		166
Fair Value of Derivative Liabilities		8		9
Fair Value, Measurements, Recurring | Level 3
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets	[2]	122		157
Total liabilities		3		7
Fair Value, Measurements, Recurring | Level 3 | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		118		152
Total liabilities		3		5
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		122		157
Fair Value of Derivative Liabilities		3		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		118		152
Fair Value of Derivative Liabilities		3		$ 5
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		7
Fair Value of Derivative Liabilities		3
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		7
Fair Value of Derivative Liabilities		$ 3
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Minimum | Liabilities
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Minimum | Liabilities | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Minimum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Minimum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Maximum | Liabilities
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Maximum | Liabilities | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Maximum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Maximum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Weighted Average | Liabilities
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3],[4]	1
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Weighted Average | Liabilities | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3],[4]	1
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Level 3 | FTRs [Member] | Commodity | Weighted Average | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3],[4]	0
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[5]	$ 90
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[5]	$ 86
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Minimum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Minimum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	(1)
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Maximum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Maximum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	6
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Weighted Average | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3],[4]	0
Discounted Cash Flow [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Commodity | Weighted Average | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3],[4]	(1)
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Physical Options [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 24
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 24
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Minimum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	24
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Minimum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	24
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Minimum | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	4.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Minimum | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	4.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Maximum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	51
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Maximum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3]	51
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Maximum | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	62.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Maximum | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	62.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Weighted Average | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3],[4]	37
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Weighted Average | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MWh	[3],[4]	37
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Weighted Average | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4],[6]	29.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Level 3 | Electricity | Electricity | Weighted Average | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4],[6]	29.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 1
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 1
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Minimum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	2
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Minimum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	2
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Minimum | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	13.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Minimum | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	13.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Maximum | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	6
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Maximum | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3]	6
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Maximum | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	35.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Maximum | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[6]	35.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Weighted Average | Assets | Market Price [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3],[4]	3
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Weighted Average | Assets | Market Price [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market price (per Dth, per MWh, per Gal) | $ / MMBTU	[3],[4]	3
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Weighted Average | Assets | Price Volatility [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4],[6]	23.00%
Option Model [Member] | Fair Value, Measurements, Recurring | Natural Gas | Level 3 | Physical Options [Member] | Weighted Average | Assets | Price Volatility [Member] | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4],[6]	23.00%
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.
[2]	Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $211 million and $88 million of assets at June 30, 2018 and December 31, 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.
[3]	Represents market prices beyond defined terms for Levels 1 and 2.
[4]	Averages weighted by volume.
[5]	Includes basis.
[6]	Represents volatilities unrepresented in published markets.

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Detail) - USD ($) $ in Millions		Jun. 30, 2018		Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		$ 250		$ 307
Derivative Liabilities		118		284
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		147	[1]	166
Derivative Liabilities		14		66
Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		34		32
Derivative Liabilities		16		8
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	5,345		5,379
Total Liabilities		118		284
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		2,453		2,466
Total Liabilities		14		66
Fair Value, Measurements, Recurring | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		34		32
Total Liabilities		16		8
Fair Value, Measurements, Recurring | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	3,529		3,493
Fair Value, Measurements, Recurring | Equity securities: | U.S. | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	1,584		1,566
Fair Value, Measurements, Recurring | Fixed Income [Member] | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	445		444
Fair Value, Measurements, Recurring | Fixed Income [Member] | Corporate debt instruments | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	227		224
Fair Value, Measurements, Recurring | Fixed Income [Member] | Government Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	1,107		1,101
Fair Value, Measurements, Recurring | Fixed Income [Member] | Government Securities [Member] | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	492		494
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	14		34
Fair Value, Measurements, Recurring | Cash equivalents and other | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	3		16
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		159		258
Derivative Liabilities		55		197
Fair Value, Measurements, Recurring | Commodity | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		126		166
Derivative Liabilities		8		9
Fair Value, Measurements, Recurring | Commodity | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		7		6
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		58		17
Derivative Liabilities		58		85
Fair Value, Measurements, Recurring | Interest rate | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		21
Derivative Liabilities		6		57
Fair Value, Measurements, Recurring | Interest rate | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		1
Derivative Liabilities		4
Fair Value, Measurements, Recurring | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		33		32
Derivative Liabilities		5		2
Fair Value, Measurements, Recurring | Foreign currency | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		33		32
Derivative Liabilities		5		2
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	3,813		3,834
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		1,751		1,750
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]	3,529		3,493
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | U.S. | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	1,584		1,566
Fair Value, Measurements, Recurring | Level 1 | Fixed Income [Member] | Government Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	270		307
Fair Value, Measurements, Recurring | Level 1 | Fixed Income [Member] | Government Securities [Member] | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	164		168
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	14		34
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	3		16
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	1,410		1,388
Total Liabilities		115		277
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		584		564
Total Liabilities		11		61
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		34		32
Total Liabilities		16		6
Fair Value, Measurements, Recurring | Level 2 | Fixed Income [Member] | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	445		444
Fair Value, Measurements, Recurring | Level 2 | Fixed Income [Member] | Corporate debt instruments | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	227		224
Fair Value, Measurements, Recurring | Level 2 | Fixed Income [Member] | Government Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	837		794
Fair Value, Measurements, Recurring | Level 2 | Fixed Income [Member] | Government Securities [Member] | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[3]	328		326
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		37		101
Derivative Liabilities		52		190
Fair Value, Measurements, Recurring | Level 2 | Commodity | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		8		14
Derivative Liabilities		5		4
Fair Value, Measurements, Recurring | Level 2 | Commodity | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		7		4
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		58		17
Derivative Liabilities		58		85
Fair Value, Measurements, Recurring | Level 2 | Interest rate | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		21
Derivative Liabilities		6		57
Fair Value, Measurements, Recurring | Level 2 | Interest rate | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		1
Derivative Liabilities		4
Fair Value, Measurements, Recurring | Level 2 | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		33		32
Derivative Liabilities		5		2
Fair Value, Measurements, Recurring | Level 2 | Foreign currency | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		33		32
Derivative Liabilities		5		2
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	122		157
Total Liabilities		3		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		118		152
Total Liabilities		3		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 Liabilities				2
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		122		157
Derivative Liabilities		3		7
Fair Value, Measurements, Recurring | Level 3 | Commodity | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		118		152
Derivative Liabilities		$ 3		5
Fair Value, Measurements, Recurring | Level 3 | Commodity | Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities				$ 2
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.
[2]	Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $211 million and $88 million of assets at June 30, 2018 and December 31, 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.
[3]	Includes investments held in the nuclear decommissioning trusts. Excludes $171 million and $27 million of assets at June 30, 2018 and December 31, 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 (Asse60

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Parenthetical) (Detail) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets measured at fair value using NAV	$ 211	$ 88
Alternative Investment, Fair Value by Fair Value Hierarchy Level and NAV [Extensible List]	us-gaap:Assets	us-gaap:Assets
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	$ 171	$ 27
Alternative Investment, Fair Value by Fair Value Hierarchy Level and NAV [Extensible List]	us-gaap:Assets	us-gaap:Assets

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	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1	$ 120	$ 130	$ 150	$ 139
Total realized and unrealized gains/income (losses):
Included in earnings	(2)	(10)	(20)	(25)
Included in other comprehensive income (loss)			1
Included in regulatory assets/liabilities	11	32	(10)	23
Settlements	(10)		(3)	12
Transfers out of Level 3			1	3
Balance at December 31	119	152	119	152
Virginia Electric and Power Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1	117	132	147	143
Total realized and unrealized gains/income (losses):
Included in earnings	(2)	(10)	(19)	(25)
Included in regulatory assets/liabilities	8	31	(11)	23
Settlements	(8)	(1)	(2)	11
Balance at December 31	115	152	115	152
Dominion Energy Gas Holdings, LLC
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1			(2)	(2)
Total realized and unrealized gains/income (losses):
Included in other comprehensive income (loss)			1	(1)
Transfers out of Level 3			1	3
Balance at December 31	$ 0	$ 0	$ 0	$ 0

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Gains and Losses Included in the Level 3 Fair Value Category) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments Gain Loss [Line Items]
Total gains (losses) included in earnings	$ (2)	$ (10)	$ (20)	$ (25)
Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Total gains (losses) included in earnings			(1)
Electric Fuel and Other Energy-Related Purchases
Derivative Instruments Gain Loss [Line Items]
Total gains (losses) included in earnings	$ (2)	$ (10)	$ (19)	$ (25)

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Detail) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains or losses included in earnings in Level 3 fair value category	$ 0	$ 0	$ 0	$ 0
Dominion Energy Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains or losses included in earnings in Level 3 fair value category	0	0	$ 0	$ 0
Dominion Energy Gas Holdings, LLC | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net changes in assets and liabilities measured at fair value on recurring basis	$ 0	$ 0

Fair Value Measurements (Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Detail) - USD ($) $ in Millions		Jun. 30, 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]	$ 29,629	$ 28,666
Junior subordinated notes	[2]	3,981	3,981
Remarketable subordinated notes	[2]	1,382	1,379
Credit facility borrowings		73
Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[1],[3]	30,779	31,233
Junior subordinated notes	[2],[3]	4,016	4,102
Remarketable subordinated notes	[2],[3]	1,294	1,446
Credit facility borrowings	[3]	73
Virginia Electric and Power Company | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[2]	11,091	11,346
Virginia Electric and Power Company | Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[2],[3]	11,799	12,842
Dominion Energy Gas Holdings, LLC | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[4]	4,062	3,570
Dominion Energy Gas Holdings, LLC | Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including securities due within one year	[3],[4]	$ 4,094	$ 3,719
[1]	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At June 30, 2018 and December 31, 2017, includes the valuation of certain fair value hedges associated with fixed rate debt of $(61) million and $(22) million, respectively.
[2]	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium.
[3]	Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issues with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.
[4]	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments.

Fair Value Measurements (Fina65

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Parenthetical) (Detail) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Valuation of certain fair value hedges associated with fixed rate debt	$ (61)	$ (22)

Derivatives and Hedge Account66

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Detail) - USD ($) $ in Millions	Jun. 30, 2018		Dec. 31, 2017
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 242		$ 303
Net Amounts of Assets Presented in the Consolidated Balance Sheet	242		303
Total derivatives, not subject to a master netting or similar arrangement	8		4
Gross Amounts of Recognized Assets, Total	250		307
Derivative Asset	250		307
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	42		99
Net Amounts	200		204
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	138		155
Net Amounts of Assets Presented in the Consolidated Balance Sheet	138		155
Total derivatives, not subject to a master netting or similar arrangement	9		11
Gross Amounts of Recognized Assets, Total	147		166
Derivative Asset	147	[1]	166
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	6		4
Net Amounts	132		151
Dominion Energy Gas Holdings, LLC
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	34		32
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	34		32
Derivative Asset	34		32
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	6		2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	28		30
Commodity contracts | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	130		174
Net Amounts of Assets Presented in the Consolidated Balance Sheet	130		174
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7		9
Net Amounts	123		165
Commodity contracts | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	21		80
Net Amounts of Assets Presented in the Consolidated Balance Sheet	21		80
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	21		80
Commodity contracts | Virginia Electric and Power Company | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	117		155
Net Amounts of Assets Presented in the Consolidated Balance Sheet	117		155
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3		4
Net Amounts	114		151
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	58		17
Net Amounts of Assets Presented in the Consolidated Balance Sheet	58		17
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	9		8
Net Amounts	49		9
Interest rate | Virginia Electric and Power Company | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	21
Net Amounts of Assets Presented in the Consolidated Balance Sheet	21
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3
Net Amounts	18
Interest rate | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	1		0
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	1		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	1		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	0		0
Foreign currency | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	33		32
Net Amounts of Assets Presented in the Consolidated Balance Sheet	33		32
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	5		2
Net Amounts	28		30
Foreign currency | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	33		32
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	33		32
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	5		2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	$ 28		$ 30
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.

Derivatives and Hedge Account67

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Detail) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 118	$ 283
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	118	283
Total derivatives, not subject to a master netting or similar arrangement		1
Gross Amounts of Recognized Liabilities, Total	118	284
Derivative Liabilities	118	284
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	42	99
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	11	46
Net Amounts	65	138
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	9	61
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	9	61
Total derivatives, not subject to a master netting or similar arrangement	5	5
Gross Amounts of Recognized Liabilities, Total	14	66
Derivative Liabilities	14	66
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	6	4
Net Amounts	3	57
Dominion Energy Gas Holdings, LLC
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	16	8
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	16	8
Derivative Liabilities	16	8
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	6	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	10	6
Commodity contracts | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	23	76
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	23	76
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7	9
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		6
Net Amounts	16	61
Commodity contracts | Exchange
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	32	120
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	32	120
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	21	80
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	11	40
Commodity contracts | Virginia Electric and Power Company | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	3	4
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	3	4
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	4
Commodity contracts | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	7	6
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	7	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	7	6
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	58	85
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	58	85
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	9	8
Net Amounts	49	77
Interest rate | Virginia Electric and Power Company | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	6	57
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	6	57
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3
Net Amounts	3	57
Interest rate | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	4	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	4	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	1	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	3	0
Foreign currency | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	5	2
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	5	2
Foreign currency | Dominion Energy Gas Holdings, LLC | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	5	2
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	5	2
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	$ 0	$ 0

Derivatives and Hedge Account68

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Detail) - 6 months ended Jun. 30, 2018		USD ($)MWhBcfgal	EUR (€)
Fixed Price - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity	[1]	75
Fixed Price - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity	[1]	27
Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative [Line Items]
Volume of derivative activity	[1]	24
Fixed Price - Natural Gas - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity	[1]	4
Basis - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity		214
Basis - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity		112
Basis - Natural Gas - Current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Volume of derivative activity		1
Basis - Natural Gas - Non-current Derivative Contract
Derivative [Line Items]
Volume of derivative activity		600
Basis - Natural Gas - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity		514
Fixed Price - Electricity - Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh	[1]	10,566,074
Fixed Price - Electricity - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh	[1]	1,061,191
Fixed Price - Electricity - Non-current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh	[1]	677,760
Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh		102,797,191
Financial Transmission Rights - Electricity- Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh		101,284,984
Liquids - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity | gal	[2]	51,019,800
Liquids - Current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Volume of derivative activity | gal		45,643,800
Foreign currency
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | €			€ 250,000,000
Foreign currency | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | €			€ 250,000,000
Foreign Exchange - Non- Current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[3],[4]	$ 280,000,000
Foreign Exchange - Non- Current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[3],[5]	280,000,000
Interest Rate - Current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[4]	600,000,000
Interest Rate - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[4]	600,000,000
Interest Rate - Non-current Derivative Contract
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[4]	5,433,632,652
Interest Rate - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[4]	1,000,000,000
Interest Rate - Non-current Derivative Contract | Dominion Energy Gas Holdings, LLC
Derivative [Line Items]
Interest rate / Foreign currency (US Dollars, Euros) | $	[5]	$ 1,050,000,000
[1]	Includes options.
[2]	Includes NGLs and oil.
[3]	Euro equivalent volumes are €250,000,000.
[4]	Maturity is determined based on final settlement period.
[5]	Maturity is based on final settlement period.

Derivatives and Hedge Account69

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Parenthetical) (Detail) - Foreign currency	Jun. 30, 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 Account70

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (248)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(26)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(8)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(1)
Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(24)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(13)
Commodity contracts | Gas
Derivative Instruments Gain Loss [Line Items]
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 1
Maximum Term	37 months
Commodity contracts | Electricity
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (9)
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (9)
Maximum Term	18 months
Commodity contracts | Other Energy Contract
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (5)
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (5)
Maximum Term	9 months
Interest rate
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (246)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (9)
Maximum Term	378 months
Interest rate | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (8)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (1)
Maximum Term	378 months
Interest rate | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (31)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (4)
Maximum Term	318 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	$ (4)
Maximum Term	96 months
Foreign currency | Dominion Energy Gas Holdings, LLC
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	$ (4)
Maximum Term	96 months
NGLs | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (5)
Commodities, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (5)
Maximum Term	9 months

Derivatives and Hedge Account71

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Detail) - USD ($) $ in Millions		Jun. 30, 2018		Dec. 31, 2017
Derivatives Fair Value [Line Items]
Derivative Asset		$ 250		$ 307
Derivative Liabilities		118		284
Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		147	[1]	166
Derivative Liabilities		14		66
Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		34		32
Derivative Liabilities		16		8
Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset		89	[2]	169	[3]
Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset	[3]	57		75
Current Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		77		163
Current Assets | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		49		75
Current Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		12		6
Current Assets | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		8
Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	161		138
Noncurrent Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		90		91	[1]
Noncurrent Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset	[5]	34		32
Noncurrent Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		82		95
Noncurrent Assets | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		77		91
Noncurrent Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		46		11
Noncurrent Assets | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		13
Noncurrent Assets | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		1
Noncurrent Assets | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		33		32
Noncurrent Assets | Foreign currency | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		33		32
Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities		69	[6]	250	[7]
Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	12		53
Current Liabilities | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[8]	13		8
Current Liabilities | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		52		195
Current Liabilities | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		8		9
Current Liabilities | Commodity contracts | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		7		6
Current Liabilities | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		12		53
Current Liabilities | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		4		44
Current Liabilities | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		1
Current Liabilities | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		5		2
Current Liabilities | Foreign currency | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		5		2
Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[9]	49		34
Noncurrent Liabilities [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities	[10]	2		13
Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[11]	3
Noncurrent Liabilities [Member] | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		3		2
Noncurrent Liabilities [Member] | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		46		32
Noncurrent Liabilities [Member] | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		13
Noncurrent Liabilities [Member] | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		3
Fair Value - Derivatives under Hedge Accounting [Member]
Derivatives Fair Value [Line Items]
Derivative Asset		102		54
Derivative Liabilities		95		191
Fair Value - Derivatives under Hedge Accounting [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset	[1]	21
Derivative Liabilities		6		57
Fair Value - Derivatives under Hedge Accounting [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		34		32
Derivative Liabilities		16		8
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset		22	[2]	11	[3]
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset	[3]	8
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		10		5
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		12		6
Fair Value - Derivatives under Hedge Accounting [Member] | Current Assets | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		8
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	80		43
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset	[5]	34		32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		1
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset		46		11
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		1
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Asset		33		32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Assets | Foreign currency | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Asset		33		32
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities		47	[6]	158	[7]
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	4		44
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[8]	13		8
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		30		103
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Commodity contracts | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		7		6
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		12		53
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		4		44
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		1
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Foreign currency
Derivatives Fair Value [Line Items]
Derivative Liabilities		5		2
Fair Value - Derivatives under Hedge Accounting [Member] | Current Liabilities | Foreign currency | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		5		2
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[9]	48		33
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities	[10]	2		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities	[11]	3
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		1
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Interest rate
Derivatives Fair Value [Line Items]
Derivative Liabilities		46		32
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		2		13
Fair Value - Derivatives under Hedge Accounting [Member] | Noncurrent Liabilities [Member] | Interest rate | Dominion Energy Gas Holdings, LLC
Derivatives Fair Value [Line Items]
Derivative Liabilities		3
Fair Value - Derivatives not under Hedge Accounting
Derivatives Fair Value [Line Items]
Derivative Asset		148		253
Derivative Liabilities		23		93
Fair Value - Derivatives not under Hedge Accounting | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		126	[1]	166
Derivative Liabilities		8		9
Fair Value - Derivatives not under Hedge Accounting | Current Assets
Derivatives Fair Value [Line Items]
Derivative Asset		67	[2]	158	[3]
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset	[3]	49		75
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		67		158
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		49		75
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets
Derivatives Fair Value [Line Items]
Derivative Asset	[4]	81		95
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		77		91	[1]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Asset		81		95
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset		77		91
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities
Derivatives Fair Value [Line Items]
Derivative Liabilities		22	[6]	92	[7]
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities	[7]	8		9
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		22		92
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity contracts | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Liabilities		8		9
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities [Member]
Derivatives Fair Value [Line Items]
Derivative Liabilities	[9]	1		1
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities [Member] | Commodity contracts
Derivatives Fair Value [Line Items]
Derivative Liabilities		$ 1		$ 1
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets 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]	Noncurrent derivatives assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.
[6]	Current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets.
[7]	Current derivative liabilities are presented in other current liabilities in Virginia Power’s Consolidated Balance Sheets.
[8]	Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.
[9]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets.
[10]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.
[11]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.

Derivatives and Hedge Account72

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Detail) - Cash Flow Hedges - USD ($) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2018		Jun. 30, 2017		Jun. 30, 2018		Jun. 30, 2017
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	$ (44)		$ 45		$ 104		$ 115
Amount of Gain (Loss) Reclassified From AOCI to Income		(44)		29		(55)		66
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	25		(42)		93		(34)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[3]	2		(5)		9		(5)
Amount of Gain (Loss) Reclassified From AOCI to Income				(1)				(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4]	25		(42)		93		(34)
Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]	(27)		18		(10)		3
Amount of Gain (Loss) Reclassified From AOCI to Income		(19)		19		(15)		1
Electric fuel and other energy-related purchases
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				2		7		2
Commodity contracts
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	(39)		44		58		131
Amount of Gain (Loss) Reclassified From AOCI to Income		(16)		21		(23)		83
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	0				0
Commodity contracts | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]	(10)		2		(6)		4
Amount of Gain (Loss) Reclassified From AOCI to Income		(2)		1		(5)		(3)
Commodity contracts | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(16)		19		(28)		81
Commodity contracts | Operating Revenue | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(2)		1		(5)		(3)
Commodity contracts | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income						(2)
Interest rate
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	9	[6]	(15)		47	[6]	(14)
Amount of Gain (Loss) Reclassified From AOCI to Income		(12)	[6]	(11)		(24)	[6]	(23)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	25	[6]	(42)		93	[6]	(34)
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]	2	[7]	(5)	[7]	9		(5)
Amount of Gain (Loss) Reclassified From AOCI to Income				(1)	[7]			(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4]	25	[7]	(42)	[7]	93		(34)
Interest rate | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]	(3)	[8]			(3)
Amount of Gain (Loss) Reclassified From AOCI to Income		(1)	[8]	(1)	[8]	(2)		(2)
Foreign currency
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	(14)	[9]	16		(1)	[9]	(2)
Amount of Gain (Loss) Reclassified From AOCI to Income		(16)	[9]	19		(8)	[9]	6
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2],[9]	0				0
Foreign currency | Dominion Energy Gas Holdings, LLC
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]	(14)	[10]	16	[10]	(1)		(1)
Amount of Gain (Loss) Reclassified From AOCI to Income		$ (16)	[10]	$ 19	[10]	$ (8)		$ 6
[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 deferred into AOCI have no associated effect in Dominion Energy Gas’ Consolidated Statements of Income.
[6]	Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges.
[7]	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.
[8]	Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in interest and related charges
[9]	Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in other income.
[10]	Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in other income.

Derivatives and Hedge Account73

Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Detail) - Derivatives Not Designated as Hedging Instruments - USD ($) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2018		Jun. 30, 2017		Jun. 30, 2018		Jun. 30, 2017
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		$ (8)	[1]	$ (7)	[1]	$ (15)	[2]	$ (11)	[2]
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(3)		(7)		(3)		(24)
Commodity contracts | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1],[3]	(3)		(7)		(3)		(24)
Commodity contracts | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		(9)	[1]	10	[1]	(3)	[2]	14	[2]
Commodity contracts | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		4	[1]	(8)	[1]	4	[2]	8	[2]
Commodity contracts | Electric fuel and other energy-related purchases
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		$ (3)	[1]	(8)	[1]	$ (16)	[2]	(32)	[2]
Commodity contracts | Other operations and maintenance
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives				$ (1)	[1]			$ (1)	[2]
[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]	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.
[3]	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

Investments (Narrative) (Detail

Investments (Narrative) (Detail) - USD ($) $ in Millions		1 Months Ended	3 Months Ended			6 Months Ended
		Aug. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Contributions to equity method affiliates						$ 134	$ 252
Investment in equity method affiliates				$ 1,710		1,710		$ 1,544	[1]
Other receivables	[2]			133		133		126	[1]
Liabilities, other deferred credits and other liabilities				17,006		17,006		16,631	[1]
Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Other receivables	[3]			22		22		15	[4]
Liabilities, other deferred credits and other liabilities				2,931		2,931		2,866	[4]
Equity in earnings on investments				5	$ 4	14	11
Dominion Energy Gas Holdings, LLC | Partnership Interest
Schedule of Equity Method Investments [Line Items]
Investment in equity method affiliates				95		95		95
Equity method investment, balance carrying value				8		8		8
Equity in earnings on investments						14	11
Distributions received from investment						14	11
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Contributions to equity method affiliates				81	85	159	202
Atlantic Coast Pipeline | DETI
Schedule of Equity Method Investments [Line Items]
Revenue				60	$ 30	106	$ 61
Other receivables				19		19		12
Atlantic Coast Pipeline | Current Liabilities
Schedule of Equity Method Investments [Line Items]
Investment in equity method affiliates				33		33
NedPower Mount Storm LLC
Schedule of Equity Method Investments [Line Items]
Liabilities, other deferred credits and other liabilities				1		1		17
Catalyst Old River Hydroelectic Limited Partnership
Schedule of Equity Method Investments [Line Items]
Equity method investment, balance carrying value				0		0
Catalyst Old River Hydroelectic Limited Partnership | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Gain on sale of equity method investment			$ 90
Gain on sale of equity method investments, net of tax			$ 65
Catalyst Old River Hydroelectic Limited Partnership | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of limited partner interests		25.00%
Limited partnership interest sale transaction, expected proceeds		$ 90
Trading Securities
Schedule of Equity Method Investments [Line Items]
Rabbi trust securities				$ 114		$ 114		$ 112
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	See Note 10 for amounts attributable to related parties.
[3]	See Note 18 for amounts attributable to related parties.
[4]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

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		Jun. 30, 2018		Dec. 31, 2017
Investment Holdings [Line Items]
Amortized Cost, Total		$ 3,277		$ 3,200
Total Unrealized Gains		1,918		1,899
Total Unrealized Losses	[1]	(36)		(6)
Fair Value		5,159		5,093
Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total		1,594		1,549
Total Unrealized Gains		871		852
Total Unrealized Losses	[2]	(16)		(2)
Fair Value		2,449		2,399
Cash Equivalents and Other [Member]
Investment Holdings [Line Items]
Amortized Cost, Total	[3]	5		34
Fair Value	[3]	5		34
Cash Equivalents and Other [Member] | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Other Investments	[4]	7		22
Fair Value	[4]	7		22
Cost Method Investments [Member]
Investment Holdings [Line Items]
Amortized Cost, Total				68
Fair Value				68
Cost Method Investments [Member] | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Other Investments				68
Fair Value				68
Common/collective trust funds | Fixed Income [Member]
Investment Holdings [Line Items]
Amortized Cost, Total	[5]	72		60
Fair Value	[5]	72		60
Common/collective trust funds | Fixed Income [Member] | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total	[6]	32		27
Fair Value	[6]	32		27
Corporate debt instruments | Fixed Income [Member]
Investment Holdings [Line Items]
Amortized Cost, Total	[5]	447		430
Total Unrealized Gains	[5]	6		15
Total Unrealized Losses	[5]	(8)		(1)
Fair Value	[5]	445		444
Corporate debt instruments | Fixed Income [Member] | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total	[6]	228		216
Total Unrealized Gains	[6],[7]	3		8
Total Unrealized Losses	[6],[7]	(4)
Fair Value	[6]	227		224
Government Securities [Member] | Fixed Income [Member]
Investment Holdings [Line Items]
Amortized Cost, Total	[5]	1,058		1,039
Total Unrealized Gains	[5]	16		27
Total Unrealized Losses	[5]	(14)		(5)
Fair Value	[5]	1,060		1,061
Government Securities [Member] | Fixed Income [Member] | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total	[6]	490		482
Total Unrealized Gains	[6],[7]	7		13
Total Unrealized Losses	[6],[7]	(5)		(2)
Fair Value	[6]	492		493
Equity securities: | U.S.
Investment Holdings [Line Items]
Amortized Cost, Total		1,695	[8]	1,569	[5]
Total Unrealized Gains		1,896	[8]	1,857	[5]
Total Unrealized Losses	[8]	(14)
Fair Value		3,577	[8]	3,426	[5]
Equity securities: | U.S. | Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total	[8]	837		734
Total Unrealized Gains	[7],[8]	861		831
Total Unrealized Losses	[7],[8]	(7)
Fair Value	[8]	$ 1,691		$ 1,565
[1]	The fair value of securities in an unrealized loss position was $900 million and $565 million at June 30, 2018 and December 31, 2017, respectively.
[2]	The fair value of securities in an unrealized loss position was $414 million and $234 million at June 30, 2018 and December 31, 2017, respectively.
[3]	Includes pending purchases of securities of $3 million at June 30, 2018 and pending sales of securities of $5 million at December 31, 2017.
[4]	Includes pending sales of securities of $5 million and $6 million at June 30, 2018 and December 31, 2017, respectively.
[5]	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.
[6]	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.
[7]	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. 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.
[8]	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.

Investments (Equity and Debt 76

Investments (Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds) (Parenthetical) (Detail) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Investment Holdings [Line Items]
Fair value of securities in an unrealized loss position	$ 900	$ 565
Net assets related to pending sales and purchases of securities	3	5
Virginia Electric and Power Company
Investment Holdings [Line Items]
Fair value of securities in an unrealized loss position	414	234
Net assets related to pending sales and purchases of securities	$ 5	$ 6

Investments (Portion of Unreali

Investments (Portion of Unrealized Gains and Losses Relates to Equity Securities) (Detail) - USD ($) $ in Millions		3 Months Ended	6 Months Ended
		Jun. 30, 2018	Jun. 30, 2018
Investment Holdings [Line Items]
Net gains recognized during the period		$ 89	$ 24
Less: Net gains recognized during the period on securities sold during the period		(16)	(35)
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018	[1]	73	(11)
Virginia Electric and Power Company
Investment Holdings [Line Items]
Net gains recognized during the period		44	12
Less: Net gains recognized during the period on securities sold during the period		(8)	(23)
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018	[1]	$ 36	$ (11)
[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	Jun. 30, 2018USD ($)
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	$ 321
Due after one year through five years	327
Due after five years through ten years	353
Due after ten years	576
Total	1,577
Virginia Electric and Power Company
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	49
Due after one year through five years	158
Due after five years through ten years	216
Due after ten years	328
Total	$ 751

Investments (Selected Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales of securities		$ 425	$ 363	$ 844	$ 1,119
Realized gains	[1]	36	23	72	117
Realized losses	[1]	23	16	42	36
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales of securities		196	168	414	498
Realized gains	[1]	15	10	33	55
Realized losses	[1]	$ 7	$ 8	$ 12	$ 18
[1]	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

Property Plant and Equipment (N

Property Plant and Equipment (Narrative) (Detail) $ in Millions	1 Months Ended				3 Months Ended		6 Months Ended
	Jun. 30, 2018USD ($)afield	Mar. 31, 2018USD ($)afield	Feb. 28, 2018USD ($)	Jan. 31, 2018a	Jun. 30, 2018USD ($)afield	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)afield	Jun. 30, 2017USD ($)	Nov. 30, 2014afield
Virginia Electric and Power Company | Assignment of Tower Rental Portfolio | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Property Plant And Equipment [Line Items]
Amount of consideration	$ 91				$ 91		$ 91
Amount recognized in operating revenue and other income from sale					1	$ 1	3	$ 8
Amount to be recognized in other income ratably through 2023	32				32		32
Dominion Energy Gas Holdings, LLC | Marcellus Shale | Oil and Gas Properties
Property Plant And Equipment [Line Items]
Amount of consideration	$ 6		$ 28		$ 6		$ 6
Development rights (number of acres) | a	9,000			18,000	9,000		9,000		24,000
Number of natural gas storage fields | field	1				1		1		1
Gas and oil area developed net remaining interest conveyed percentage				50.00%
Dominion Energy Gas Holdings, LLC | Marcellus Shale | Oil and Gas Properties | Other operations and maintenance
Property Plant And Equipment [Line Items]
Gain from sale	$ 6		28
After tax gain on sale	$ 4		$ 20
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
Number of natural gas storage fields | field		1
Proceeds from assignment of Shale Development Rights		$ 16
Dominion Energy Gas Holdings, LLC | Utica and Point Pleasant Shale | Oil and Gas Properties | Other operations and maintenance
Property Plant And Equipment [Line Items]
Gain from sale		16
After tax gain on sale		$ 12

Regulatory Assets and Liabili81

Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Detail) - USD ($) $ in Millions		Jun. 30, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]	$ 424	$ 193
Regulatory liabilities-noncurrent		7,065	6,916	[2]
Total regulatory liabilities		7,489	7,109
Reserve for rate credits to customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	200
Provision for future cost of removal and AROs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[4]	101	101
Regulatory liabilities-noncurrent	[4]	1,407	1,384
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		123	92
Regulatory liabilities-noncurrent		390	353
Nuclear decommissioning trust
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[5]	1,147	1,121
Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[6]	4,037	4,058
Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[7]	84
Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		305	127
Regulatory liabilities-noncurrent		4,877	4,760	[8]
Total regulatory liabilities		5,182	4,887
Virginia Electric and Power Company | Reserve for rate credits to customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	200
Virginia Electric and Power Company | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		25	47
Regulatory liabilities-noncurrent		99	74
Virginia Electric and Power Company | Nuclear decommissioning trust
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[5]	1,147	1,121
Virginia Electric and Power Company | Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[6]	2,567	2,581
Virginia Electric and Power Company | Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[7]	72
Virginia Electric and Power Company | Provision for future cost of removal
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[4]	80	80
Regulatory liabilities-noncurrent	[4]	927	915
Virginia Electric and Power Company | Derivatives
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[9]	65	69
Dominion Energy Gas Holdings, LLC
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]	48	38
Regulatory liabilities-noncurrent		1,253	1,227	[10]
Total regulatory liabilities		1,301	1,265
Dominion Energy Gas Holdings, LLC | Provision for future cost of removal and AROs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[4]	13	13
Regulatory liabilities-noncurrent	[5]	165	160
Dominion Energy Gas Holdings, LLC | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		14	5
Regulatory liabilities-noncurrent		84	69
Dominion Energy Gas Holdings, LLC | Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[6]	993	998
Dominion Energy Gas Holdings, LLC | Cost-of-service impact of 2017 Tax Reform Act
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[7]	11
Dominion Energy Gas Holdings, LLC | PIPP
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[11]	3	$ 20
Dominion Energy Gas Holdings, LLC | Overrecovered gas costs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[12]	$ 18
[1]	Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets.
[2]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[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]	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.
[5]	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.
[6]	Amounts recorded to pass the effect of reduced income taxes 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.
[7]	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.
[8]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[9]	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.
[10]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[11]	Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rate adjustment clause according to East Ohio tariff provisions.
[12]	Reflects unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings with the applicable regulatory authority.

Regulatory Assets and Liabili82

Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Detail) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2018	Dec. 31, 2017
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	$ 616	$ 294	[2]
Regulatory assets-noncurrent		2,395	2,480	[2]
Total regulatory assets		3,011	2,774
Deferred cost of fuel used in electric generation
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	344	23
Deferred rate adjustment clause costs
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	89	70
Regulatory assets-noncurrent	[4]	372	401
Deferred nuclear refueling outage costs
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	$ 76	54
Deferred nuclear refueling outage costs | Maximum
Regulatory Assets [Line Items]
Amortization period for deferred costs		18 months
Unrecovered gas costs
Regulatory Assets [Line Items]
Regulatory assets-current	[6]	$ 3	38
Other
Regulatory Assets [Line Items]
Regulatory assets-current		104	109
Regulatory assets-noncurrent		185	151
Unrecognized pension and other postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[7]	1,296	1,336
PJM transmission rates
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[8]	237	222
Derivatives
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[9]	131	223
Utility reform legislation
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[10]	174	147
Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	552	205	[11]
Regulatory assets-noncurrent		729	810	[11]
Total regulatory assets		1,281	1,015
Virginia Electric and Power Company | Deferred cost of fuel used in electric generation
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	344	23
Virginia Electric and Power Company | Deferred rate adjustment clause costs
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	56	56
Regulatory assets-noncurrent	[4]	296	312
Virginia Electric and Power Company | Deferred nuclear refueling outage costs
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	76	54
Virginia Electric and Power Company | Other
Regulatory Assets [Line Items]
Regulatory assets-current		76	72
Regulatory assets-noncurrent		98	86
Virginia Electric and Power Company | PJM transmission rates
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[8]	237	222
Virginia Electric and Power Company | Derivatives
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[9]	98	190
Dominion Energy Gas Holdings, LLC
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	35	26
Regulatory assets-noncurrent	[12]	526	511
Total regulatory assets		561	537
Dominion Energy Gas Holdings, LLC | Deferred rate adjustment clause costs
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	33	14
Regulatory assets-noncurrent	[4]	76	89
Dominion Energy Gas Holdings, LLC | Unrecovered gas costs
Regulatory Assets [Line Items]
Regulatory assets-current	[6]	0	8
Dominion Energy Gas Holdings, LLC | Other
Regulatory Assets [Line Items]
Regulatory assets-current		2	4
Regulatory assets-noncurrent		25	17
Dominion Energy Gas Holdings, LLC | Unrecognized pension and other postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[7]	251	258
Dominion Energy Gas Holdings, LLC | Utility reform legislation
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[10]	$ 174	$ 147
[1]	Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.
[2]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Dominion Energy and Virginia Power’s generation operations.
[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]	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.
[6]	Reflects unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings with the applicable regulatory authority.
[7]	Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered or refunded through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy's and Dominion Energy Gas' rate-regulated subsidiaries.
[8]	Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information.
[9]	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.
[10]	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.
[11]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[12]	Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.

Regulatory Assets and Liabili83

Regulatory Assets and Liabilities (Narrative) (Detail) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2018	Dec. 31, 2017
Public Utilities, General Disclosures [Line Items]
Regulatory assets past expenditures not earning return		$ 427
Regulatory assets		$ 2,395	$ 2,480	[1]
Period for which expenditures are expected to be recovered		2 years
PJM transmission rates
Public Utilities, General Disclosures [Line Items]
Regulatory assets	[2]	$ 237	222
Virginia Electric and Power Company
Public Utilities, General Disclosures [Line Items]
Regulatory assets past expenditures not earning return		349
Regulatory assets		729	810	[3]
Virginia Electric and Power Company | PJM transmission rates
Public Utilities, General Disclosures [Line Items]
Regulatory assets	[2]	$ 237	$ 222
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information.
[3]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Regulatory Matters (Narrative)

Regulatory Matters (Narrative) (Detail) $ in Millions

1 Months Ended

3 Months Ended

6 Months Ended

Jul. 31, 2018USD ($)project

Jun. 30, 2018USD ($)kVpower_stationmi

May 31, 2018USD ($)kVmi

Feb. 28, 2018USD ($)

Oct. 31, 2017USD ($)program

Jun. 30, 2016

Aug. 31, 2009kV

Apr. 30, 2008

Apr. 30, 2007kV

Jun. 30, 2018USD ($)MMcf

Jun. 30, 2017USD ($)

Jun. 30, 2018USD ($)kVmi

Jun. 30, 2017USD ($)

Dec. 31, 2017USD ($)

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

$ 2,395

$ 2,395

$ 2,395

$ 2,480

[1]

Cost of project

51

$ 280

Regulatory asset recovered through retail rates

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

[2]

237

237

237

222

Virginia Regulation | Operating Segments

Public Utilities General Disclosures [Line Items]

Charge associated with legislation

215

Charge associated with legislation, after tax

160

Virginia Electric and Power Company

Public Utilities General Disclosures [Line Items]

ROE (percentage)

11.40%

Regulatory assets-noncurrent

729

729

729

810

[3]

Interim reduction in generation and distribution services on annual basis

$ 125

Cost of project

43

$ 3

Virginia Electric and Power Company | Regulatory asset recovered through retail rates

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

[2]

$ 237

237

$ 237

$ 222

Virginia Electric and Power Company | Virginia Regulation

Public Utilities General Disclosures [Line Items]

Estimated recovery of fuel expenses

1,500

Proposed increase in fuel revenue

$ 222

Earnings above authorized return on equity (basis points)

0.70%

One-time bill credit, provisions for current customers

$ 200

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

Length of kV line (miles) | mi

5

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Between the Chesterfield and Hopewell Substations

Public Utilities General Disclosures [Line Items]

Capacity of transmission line (kV) | kV

230

Length of kV line (miles) | mi

8

Total estimated cost of project

$ 30

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Between the Chesterfield and Lakeside Substations

Public Utilities General Disclosures [Line Items]

Capacity of transmission line (kV) | kV

230

Length of kV line (miles) | mi

21

Total estimated cost of project

$ 35

Virginia Electric and Power Company | Virginia Regulation | Transmission Line Between the Landstown and Thrasher Substations

Public Utilities General Disclosures [Line Items]

Capacity of transmission line (kV) | kV

230

Length of kV line (miles) | mi

8.5

Total estimated cost of project

$ 20

20

$ 20

Virginia Electric and Power Company | Virginia Regulation | Four Separate Segments of Line # 224

Public Utilities General Disclosures [Line Items]

Capacity of transmission line (kV) | kV

230

Total estimated cost of project

$ 35

35

35

Virginia Electric and Power Company | Virginia Regulation | Operating Segments

Public Utilities General Disclosures [Line Items]

Charge associated with legislation

215

Charge associated with legislation, after tax

160

Reduction in base rate on annual basis

125

Estimated capital investment for first three years

816

816

816

Proposed operations and maintenance expenses for first three years

$ 102

Electric distribution grid transformation project duration

10 years

Proposed revenue requirement

755

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

468

Virginia Electric and Power Company | Virginia Regulation | Operating Segments | Colonial Trail West and Spring Grove 1 Solar Facilities | Subsequent Event

Public Utilities General Disclosures [Line Items]

Cost of project

$ 410

Number of solar facilities to be construct | project

2

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

287

Increase (decrease) in revenue requirement

146

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

220

Increase (decrease) in revenue requirement

2

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

107

Increase (decrease) in revenue requirement

(2)

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

59

Increase (decrease) in revenue requirement

(7)

Virginia Electric and Power Company | Virginia Regulation | Rider B

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 54

Increase (decrease) in revenue requirement

$ 7

Number of power stations converted to biomass | power_station

3

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 121

Increase (decrease) in revenue requirement

39

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 31

Increase (decrease) in revenue requirement

$ 3

Number of new energy efficiency programs | program

1

Period for cost cap

5 years

Amount of cost recovery

$ 25

Approved revenue required

31

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

132

Increase (decrease) in revenue requirement

5

Virginia Electric and Power Company | Virginia Regulation | Rider BW | Operating Segments | Subsequent Event

Public Utilities General Disclosures [Line Items]

Approved revenue required

$ 116

Virginia Electric and Power Company | Virginia Regulation | Rider US-2 | Operating Segments

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

15

Increase (decrease) in revenue requirement

$ 5

Virginia Electric and Power Company | Virginia Regulation | Rider US-2 | Operating Segments | Subsequent Event

Public Utilities General Disclosures [Line Items]

Approved revenue required

13

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

Public Utilities General Disclosures [Line Items]

Proposed revenue requirement

$ 11

Virginia Electric and Power Company | Settled Litigation | Federal Energy Regulatory Commission | Order Regarding Transmission Rate Design For Allocation Of Costs Among P J M Interconnect L L C Transmission Customers | Unfavorable Regulatory Action

Public Utilities General Disclosures [Line Items]

Duration of payment under settlement agreement

10 years

Virginia Electric and Power Company | Settled Litigation | Federal Energy Regulatory Commission | Order Regarding Transmission Rate Design For Allocation Of Costs Among P J M Interconnect L L C Transmission Customers | Unfavorable Regulatory Action | Other Current Liabilities

Public Utilities General Disclosures [Line Items]

Amount of contingent liability

148

148

$ 148

Virginia Electric and Power Company | Settled Litigation | Federal Energy Regulatory Commission | Order Regarding Transmission Rate Design For Allocation Of Costs Among P J M Interconnect L L C Transmission Customers | Unfavorable Regulatory Action | Other Deferred Credits and Other Liabilities

Public Utilities General Disclosures [Line Items]

Amount of contingent liability

98

98

98

Virginia Electric and Power Company | Settled Litigation | Federal Energy Regulatory Commission | Order Regarding Transmission Rate Design For Allocation Of Costs Among P J M Interconnect L L C Transmission Customers | Unfavorable Regulatory Action | Regulatory asset recovered through retail rates

Public Utilities General Disclosures [Line Items]

Regulatory assets-noncurrent

$ 237

237

$ 237

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 [Member]

Public Utilities General Disclosures [Line Items]

Facility operating capacity (kV) | kV

500

DETI | Federal Energy Regulatory Commission | Other operations and maintenance | Preliminary recommendation one

Public Utilities General Disclosures [Line Items]

Audit compliance charge recognized in connection with preliminary recommendation

$ 15

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

$ 9

DETI | Federal Energy Regulatory Commission | Other operations and maintenance | Other preliminary recommendation

Public Utilities General Disclosures [Line Items]

Audit compliance charge recognized in connection with preliminary recommendation

129

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

$ 94

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

Public Utilities General Disclosures [Line Items]

Reduction in regulatory liabilities

15

Questar Gas | Utah and Wyoming Regulation

Public Utilities General Disclosures [Line Items]

LNG peaking storage facility, liquefaction rate per day | MMcf

8.2

Number of days to make prudency determination

180 days

Proposed cost increase (decrease) amount

86

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

Public Utilities General Disclosures [Line Items]

Refund of over-recovery of accumulated arrearages

4

Recovery of projected deferred program costs

10

East Ohio | Ohio Regulation | UEX Rider

Public Utilities General Disclosures [Line Items]

Elimination of over-recovered balance of accumulated bad debt expense

11

Prospective bad debt expense recovered

16

Hope Gas, Inc. | West Virginia Regulation | Pipeline Infrastructure Replacement Program

Public Utilities General Disclosures [Line Items]

Amount of cost recovery

8

Projected capital investment, current year

31

Projected capital investment, next year

36

Projected capital investment, previous year

$ 28

[1]

Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

[2]

Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information.

[3]

Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Detail) $ in Millions		3 Months Ended		6 Months Ended		9 Months Ended
		Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)MW	Jun. 30, 2017USD ($)	Sep. 30, 2017generator	Dec. 31, 2017USD ($)
Variable Interest Entity [Line Items]
Securities due within one year		$ 2,950		$ 2,950			$ 3,078	[1]
Long term debt		32,115		32,115			30,948	[1]
Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Securities due within one year	[2]						850
Long term debt		11,091		11,091			10,496	[2]
Affiliated current borrowings		25		25			33	[2]
Dominion Energy Gas Holdings, LLC
Variable Interest Entity [Line Items]
Long term debt		4,062		4,062			3,570	[3]
Affiliated current borrowings		56		56			18	[3]
Variable Interest Entity, Primary Beneficiary | SBL Holdco
Variable Interest Entity [Line Items]
Securities due within one year		29		29
Long term debt		324		$ 324
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) | generator						3
Number of expired non-utility generators | generator						2
Aggregate generation capacity from long-term power and capacity contracts (MW) | MW				218
Remaining purchase commitments		175		$ 175
Payment for electric capacity		12	$ 28	25	$ 56
Other energy-related purchases		5	7	10	15
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company | DES
Variable Interest Entity [Line Items]
Shared services purchased		83	83	172	168
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company | DES | Payables to Affiliates
Variable Interest Entity [Line Items]
Affiliated current borrowings		35		35			36
Variable Interest Entity, Not Primary Beneficiary | Dominion Energy Gas Holdings, LLC | DES
Variable Interest Entity [Line Items]
Shared services purchased		31	$ 31	63	$ 62
Variable Interest Entity, Not Primary Beneficiary | Dominion Energy Gas Holdings, LLC | DES | Payables to Affiliates
Variable Interest Entity [Line Items]
Affiliated current borrowings		$ 12		$ 12			$ 14
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Significant Financing Transac86

Significant Financing Transactions (Narrative) (Detail)		1 Months Ended								2 Months Ended	3 Months Ended				6 Months Ended
		Jun. 30, 2018USD ($)		May 31, 2018USD ($)	Apr. 30, 2018USD ($)$ / shares	Mar. 31, 2018USD ($)facility	Feb. 28, 2018USD ($)agreement	Jan. 31, 2018USD ($)shares	Jun. 30, 2017USD ($)agreement	Apr. 30, 2018USD ($)$ / sharesshares	Jun. 30, 2018USD ($)shares		Mar. 31, 2018USD ($)facility	Jun. 30, 2017shares	Jun. 30, 2018USD ($)shares		Jun. 30, 2017USD ($)shares	Dec. 31, 2017USD ($)
Debt Instrument [Line Items]
Number of joint revolving credit facilities | facility						2							2
Short-term debt		$ 2,745,000,000									$ 2,745,000,000				$ 2,745,000,000			$ 3,298,000,000	[1]
Guarantee recorded amount		73,000,000									73,000,000				73,000,000
Issuance of common stock															662,000,000		$ 156,000,000
Aggregate proceeds from issuance of shares of common stock															$ 662,000,000		$ 156,000,000
Common Stock
Debt Instrument [Line Items]
Issuance of common stock (in shares) | shares															9,000,000		2,000,000
Issuance of common stock															$ 662,000,000		$ 156,000,000
Common Stock | Forward Sale Agreements
Debt Instrument [Line Items]
Issuance of shares of common stock under forward equity sale agreement | shares										20,000,000
Aggregate proceeds from issuance of shares of common stock										$ 1,500,000,000
Maximum | Common Stock | Forward Sale Agreements
Debt Instrument [Line Items]
Full physical settlement of forward sale agreements date										Dec. 31, 2018
Shelf Registration For Sale Of Common Stock Through At Market Program
Debt Instrument [Line Items]
Number of sales agency agreements | agreement							6		3
Issuance of common stock (in shares) | shares								6,600,000
Issuance of common stock							$ 0	$ 495,000,000
Fees and commissions paid								5,000,000
Shelf Registration For Sale Of Common Stock Through At Market Program | Maximum
Debt Instrument [Line Items]
Sale of stock authorized amount							1,000,000,000		$ 500,000,000
Underwriters Option to Purchase | Common Stock | Forward Sale Agreements
Debt Instrument [Line Items]
Issuance of shares of common stock under option to purchase | shares										2,100,000
Issuance of shares of common stock under option to purchase, price per share | $ / shares					$ 67.33					$ 67.33
Period to purchase common stock under option										30 days
Underwriters Option to Purchase | Maximum | Common Stock | Forward Sale Agreements
Debt Instrument [Line Items]
Issuance of shares of common stock under option to purchase | shares										3,000,000
Dominion Energy Midstream Partners, LP | Limited Partner | Dominion Midstream Limited Partner Common Unit Purchase Program
Debt Instrument [Line Items]
Common units conversion basis															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.
Common units conversion basis ratio													100.00%
Number of common units received on incentive distribution right | shares															27,000,000
Change in noncontrolling interest															$ 375,000,000
Dominion Energy Midstream Partners, LP | Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit						$ 500,000,000							$ 500,000,000
Line of credit facility maturity date						Mar. 31, 2021
Guarantee recorded amount		73,000,000									73,000,000				73,000,000
Dominion Energy Midstream Partners, LP | Revolving Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Facility Limit						$ 250,000,000							250,000,000
Virginia Electric and Power Company
Debt Instrument [Line Items]
Short-term debt		1,158,000,000									$ 1,158,000,000				$ 1,158,000,000			542,000,000	[2]
Credit facility						100,000,000							100,000,000
Issuance of common stock (in shares) | shares											0			0	0		0
Virginia Electric and Power Company | Tax Exempt Financing
Debt Instrument [Line Items]
Repayment of variable rate tax-exempt financings						100,000,000
Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Short-term debt		188,000,000									$ 188,000,000				$ 188,000,000			$ 629,000,000	[3]
$6 billion Joint Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit		6,000,000,000	[4]			6,000,000,000					6,000,000,000	[4]	6,000,000,000		6,000,000,000	[4]
$6 billion Joint Revolving Credit Facility | Questar Gas
Debt Instrument [Line Items]
Facility Limit		250,000,000									250,000,000				250,000,000
$6 billion Joint Revolving Credit Facility | Virginia Electric and Power Company
Debt Instrument [Line Items]
Facility Limit	[5]	6,000,000,000									6,000,000,000				6,000,000,000
$6 billion Joint Revolving Credit Facility | Dominion Energy Gas Holdings, LLC
Debt Instrument [Line Items]
Facility Limit	[6]	1,500,000,000									1,500,000,000				1,500,000,000
Credit Facilities, Maturing in December 2017 with 1 year Automatic Renewals through 2023 | SBL Holdco
Debt Instrument [Line Items]
Facility Limit		30,000,000									30,000,000				$ 30,000,000
Automatic renewal period															1 year
Short-term debt		0									0				$ 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									25,000,000				$ 25,000,000
Automatic renewal period															1 year
Short-term debt		0									0				$ 0
Term Loan Credit Agreement [Member]
Debt Instrument [Line Items]
Guarantee recorded amount		$ 500,000,000					$ 950,000,000				500,000,000				500,000,000
Duration of credit facilities		364 days					364 days
Maximum allowed total debt to total capital ratio		67.50%					67.50%
3.53% Due 2028 | Dominion Energy Midstream Partners, LP | Private Placement
Debt Instrument [Line Items]
Total Long-term Debt								$ 100,000,000
Interest rate percentage								3.53%
Debt maturity year								2,028
3.91% Due 2038 | Dominion Energy Midstream Partners, LP | Private Placement
Debt Instrument [Line Items]
Total Long-term Debt								$ 150,000,000
Interest rate percentage								3.91%
Debt maturity year								2,038
Senior Notes, Due in 2028 | Senior Notes
Debt Instrument [Line Items]
Total Long-term Debt		$ 300,000,000									$ 300,000,000				$ 300,000,000
Interest rate percentage		4.25%									4.25%				4.25%
Debt maturity year		2,028
Senior Notes, Due in 2028 | Virginia Electric and Power Company | Senior Notes
Debt Instrument [Line Items]
Total Long-term Debt						$ 700,000,000							$ 700,000,000
Interest rate percentage						3.80%							3.80%
Debt maturity year						2,028
3.30% Due 2030 | Questar Gas | Private Placement
Debt Instrument [Line Items]
Total Long-term Debt					$ 50,000,000					$ 50,000,000
Interest rate percentage					3.30%					3.30%
Debt maturity year					2,030
3.97% Due 2047 | Questar Gas | Private Placement
Debt Instrument [Line Items]
Total Long-term Debt					$ 100,000,000					$ 100,000,000
Interest rate percentage					3.97%					3.97%
Debt maturity year					2,047
Senior Notes, Due in 2020 | Senior Notes
Debt Instrument [Line Items]
Total Long-term Debt				$ 500,000,000
Debt maturity year				2,020
Senior Notes, Due in 2021 | Dominion Energy Gas Holdings, LLC | Senior Notes
Debt Instrument [Line Items]
Total Long-term Debt		$ 500,000,000									$ 500,000,000				$ 500,000,000
Debt maturity year		2,021
[1]	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[4]	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.
[5]	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 June 30, 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.
[6]	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 June 30, 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.

Significant Financing Transac87

Significant Financing Transactions (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Detail) - $6 billion Joint Revolving Credit Facility - USD ($)		Jun. 30, 2018		Mar. 31, 2018
Line of Credit Facility [Line Items]
Facility Limit		$ 6,000,000,000	[1]	$ 6,000,000,000
Outstanding Commercial Paper	[1]	2,743,000,000
Outstanding Letters of Credit	[1]	72,000,000
Facility Capacity Available	[1]	3,185,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	[2]	6,000,000,000
Outstanding Commercial Paper	[2]	1,158,000,000
Outstanding Letters of Credit	[2]	1,000,000
Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	[3]	1,500,000,000
Outstanding Commercial Paper	[3]	188,000,000
Outstanding Letters of Credit	[3]	$ 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 June 30, 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 June 30, 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.

Significant Financing Transac88

Significant Financing Transactions (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Parenthetical) (Detail) - $6 billion Joint Revolving Credit Facility - USD ($)		Jun. 30, 2018		Mar. 31, 2018
Line of Credit Facility [Line Items]
Facility Limit		$ 6,000,000,000	[1]	$ 6,000,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	[2]	6,000,000,000
Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	[3]	1,500,000,000
Letter of Credit
Line of Credit Facility [Line Items]
Facility Limit		2,000,000,000
Letter of Credit | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit		2,000,000,000
Letter of Credit | Dominion Energy Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit		1,500,000,000
Line of Credit | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit		1,500,000,000
Line of Credit | 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 June 30, 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 June 30, 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.

Commitments and Contingencies89

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

1 Months Ended

6 Months Ended

Sep. 30, 2017petition

Jul. 31, 2017

Jun. 30, 2017

May 31, 2017count

Apr. 30, 2017petitionstation

Mar. 31, 2017count

Aug. 31, 2016T

Jul. 31, 2016party

Oct. 31, 2015ppb

Jun. 30, 2015party

Apr. 30, 2015facility

Oct. 31, 2014facilitygal

Jun. 30, 2014

Jun. 30, 2018USD ($)facilitysiteparty

Apr. 30, 2016USD ($)

Jul. 31, 2013count

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

Loss Contingencies [Line Items]

ARO incurred

$ 131

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

Loss Contingencies [Line Items]

ARO incurred

46

Virginia Electric and Power Company | Increase In Regulatory Assets

Loss Contingencies [Line Items]

ARO incurred

4

Virginia Electric and Power Company | Other operations and maintenance

Loss Contingencies [Line Items]

ARO incurred

81

ARO incurred after tax

60

CWA | Virginia Electric and Power Company | Minimum | Possum Point Power Station | Judicial Ruling [Member]

Loss Contingencies [Line Items]

Additional specific sediment, water and aquatic life monitoring period

2 years

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

Loss Contingencies [Line Items]

Compliance date

2023-12

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

Loss Contingencies [Line Items]

Compliance date

2020-11

CCR | EPA

Loss Contingencies [Line Items]

Number of petition agreed for reconsideration | petition

2

Unfavorable Regulatory Action | EPA

Loss Contingencies [Line Items]

Significant emission rate per rear CO2 equivalent | T

75,000

Public Utilities Electricity generating facilitties Minimum regulatory Threshold per day | gal

2,000,000

Unfavorable Regulatory Action | EPA | Minimum

Loss Contingencies [Line Items]

Electric generating station facilities heightened entrainment analysis per day | gal

125,000,000

Unfavorable Regulatory Action | MATS | EPA

Loss Contingencies [Line Items]

Requested compliance extension under EPA Administrative Order

1 year

Extension period for MATS compliance

1 year

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

Period to be in service following receipt of all required permits

23 months

Unfavorable Regulatory Action | Ozone Standards | EPA

Loss Contingencies [Line Items]

Standard emission level prior to revision | ppb

75

Revised emission standard level | ppb

70

Unfavorable Regulatory Action | Ozone Standards | EPA | Virginia Electric and Power Company | Minimum

Loss Contingencies [Line Items]

Estimated compliance costs

25

Unfavorable Regulatory Action | Ozone Standards | EPA | Virginia Electric and Power Company | Maximum

Loss Contingencies [Line Items]

Estimated compliance costs

$ 35

Unfavorable Regulatory Action | Regulations to Reduce Nitrogen Oxide and Volatile Organic Compounds Emissions [Member] | Pennsylvania Department Of Environmental Protection [Member] | Dominion Gas Holdings L L C

Loss Contingencies [Line Items]

Estimated compliance costs

$ 35

Unfavorable Regulatory Action | Oil And Gas New Source Performance Standards

Loss Contingencies [Line Items]

Number of period court appeals DC vacated stay

90 days

Unfavorable Regulatory Action | Oil And Gas New Source Performance Standards | EPA

Loss Contingencies [Line Items]

Requested compliance extension under EPA Administrative Order

2 years

EPA notice issued reviewing month and year

2017-04

Number of period EPA published notice of reconsideration and partial stay

90 days

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

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

Loss Contingencies [Line Items]

Number of facilities that maybe subject to additional wastewater treatment requirements | facility

8

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

19

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

2

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

Loss Contingencies [Line Items]

Estimated compliance costs

$ 18

Number of former manufactured gas plant sites | site

3

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

Loss Contingencies [Line Items]

Loss contingency loss in period

$ 16

Loss contingency loss in period after tax

$ 12

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

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

Loss Contingencies [Line Items]

Number of facilities with CCR | facility

8

Number of stations | station

4

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

Loss Contingencies [Line Items]

Total number of counts in complaint | count

8

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

Loss Contingencies [Line Items]

Accrued liability for legal matter

$ 14

Breach of Contract Lawsuit | DETI | Judicial Ruling [Member]

Loss Contingencies [Line Items]

Number of counts dismissed | count

3

Breach of Contract Lawsuit | DETI | Settled Litigation

Loss Contingencies [Line Items]

Number of claims withdrew | count

1

Liquefaction Project | Federal Energy Regulatory Commission | Cove Point | Pending Litigation [Member]

Loss Contingencies [Line Items]

Number of parties | party

2

Liquefaction Project | Federal Energy Regulatory Commission | Cove Point | Judicial Ruling [Member]

Loss Contingencies [Line Items]

Number of parties | party

1

1

Commitments and Contingencies90

Commitments and Contingencies (Nuclear Operations) (Narrative) (Detail) - USD ($)	3 Months Ended
	Jun. 30, 2018	Mar. 31, 2018
Nuclear Obligations
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount	$ 13,100,000,000	$ 13,400,000,000

Commitments and Contingencies91

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Detail) - USD ($)		1 Months Ended	6 Months Ended
		Oct. 31, 2017	Jun. 30, 2018
Guarantee Obligations [Line Items]
Maximum Exposure	[1]		$ 5,455,000,000
Commodity Transactions
Guarantee Obligations [Line Items]
Maximum Exposure	[2]		2,142,000,000
Nuclear Obligations
Guarantee Obligations [Line Items]
Maximum Exposure	[3]		200,000,000
Cove Point
Guarantee Obligations [Line Items]
Maximum Exposure	[4]		1,900,000,000
Financial Guarantee [Member] | Equity Method Investee [Member]
Guarantee Obligations [Line Items]
Maximum Exposure			48,000,000
Financial Guarantee [Member] | Affiliated Entity
Guarantee Obligations [Line Items]
Maximum Exposure			10,000,000
Financial Guarantee [Member] | Affiliated Entity | Minimum
Guarantee Obligations [Line Items]
Maximum annual future contributions			4,000,000
Financial Guarantee [Member] | Affiliated Entity | Maximum
Guarantee Obligations [Line Items]
Maximum annual future contributions			6,000,000
Financial Guarantee [Member] | Atlantic Coast Pipeline | Revolving Credit Facility
Guarantee 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			30,000,000
Guarantee recorded amount			877,000,000
Solar
Guarantee Obligations [Line Items]
Maximum Exposure	[5]		636,000,000
Other
Guarantee Obligations [Line Items]
Maximum Exposure	[6]		577,000,000
Surety Bond [Member]
Guarantee Obligations [Line Items]
Maximum Exposure			165,000,000
Surety Bond [Member] | Virginia Electric and Power Company
Guarantee Obligations [Line Items]
Maximum Exposure			70,000,000
Surety Bond [Member] | Dominion Energy Gas Holdings, LLC
Guarantee Obligations [Line Items]
Maximum Exposure			24,000,000
Financial Standby Letter of Credit [Member]
Guarantee Obligations [Line Items]
Maximum Exposure			$ 72,000,000
[1]	Excludes Dominion Energy's guarantee for the construction of a new corporate office property as discussed in Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018.
[2]	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.
[3]	Guarantees related to certain DGI subsidiaries regarding all aspects of running a nuclear facility.
[4]	Guarantees related to Cove Point, in support of terminal services, transportation and construction.
[5]	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.
[6]	Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Due to the uncertainty of workers’ 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 June 30, 2018, Dominion Energy's maximum remaining cumulative exposure under these equity funding agreements is $10 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $6 million.

Credit Risk (Narrative) (Detail

Credit Risk (Narrative) (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)counterparty	Dec. 31, 2017USD ($)
Concentration Risk and Guarantor Obligations [Line Items]
Gross credit exposure	$ 67
Additional collateral to be posted if the credit related contingent features were triggered	11	$ 62
Aggregate fair value of all derivative instruments with credit contingent provisions that are in a liability position	13	$ 65
Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Gross credit exposure	52
Wholesale Customers | Dominion Energy Gas Holdings, LLC
Concentration Risk and Guarantor Obligations [Line Items]
Gross credit exposure	$ 1
Credit Concentration Risk
Concentration Risk and Guarantor Obligations [Line Items]
Number of counterparties | counterparty	0
Amount of exposure for single counterparty	$ 7
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	$ 1
Credit Concentration Risk | Wholesale Customers | Sales Revenue, Net | Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Number of counterparties | counterparty	0
Amount of exposure related to sales to wholesale customers for single counterparty	$ 9
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	30.00%
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty | Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	24.00%
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty | Dominion Energy Gas Holdings, LLC
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	82.00%

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Detail) - USD ($)	3 Months Ended			6 Months Ended
	Jun. 30, 2018		Jun. 30, 2017	Jun. 30, 2018		Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Derivative Asset	$ 250,000,000			$ 250,000,000			$ 307,000,000
Derivative Liabilities	118,000,000			118,000,000			284,000,000
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Derivative Asset	147,000,000	[1]		147,000,000	[1]		166,000,000
Derivative Liabilities	14,000,000			14,000,000			66,000,000
Short term demand note	25,000,000			25,000,000			33,000,000	[2]
Outstanding borrowings, net of repayments, under money pool for non-regulated subsidiaries	$ 0			$ 0			0
Issuance of common stock (in shares)	0		0	0		0
Virginia Electric and Power Company | Maximum
Related Party Transaction [Line Items]
Interest charges on borrowings	$ 1,000,000		$ 1,000,000	$ 1,000,000		$ 1,000,000
Virginia Electric and Power Company | Pension Benefits | Amounts Associated with the Dominion Pension Plan
Related Party Transaction [Line Items]
Amounts due to Dominion, noncurrent	569,000,000			569,000,000			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	236,000,000			236,000,000			199,000,000
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Derivative Asset	9,000,000			9,000,000			11,000,000
Derivative Liabilities	5,000,000			5,000,000			5,000,000
Virginia Electric and Power Company | Principal Owner
Related Party Transaction [Line Items]
Short term demand note	25,000,000			25,000,000			33,000,000
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Derivative Asset	34,000,000			34,000,000			32,000,000
Derivative Liabilities	16,000,000			16,000,000			8,000,000
Short term demand note	56,000,000			56,000,000			18,000,000	[3]
Dominion Energy Gas Holdings, LLC | Revolving Credit Facility | IRCA
Related Party Transaction [Line Items]
Short term demand note	56,000,000			56,000,000			18,000,000
Dominion Energy Gas Holdings, LLC | Dominion Energy
Related Party Transaction [Line Items]
Derivative Asset	0			0
Derivative Liabilities	7,000,000			7,000,000
Dominion Energy Gas Holdings, LLC | Pension Benefits | Amounts Associated with the Dominion Pension Plan
Related Party Transaction [Line Items]
Amounts due from Dominion, noncurrent	753,000,000			753,000,000			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	$ 10,000,000			$ 10,000,000			$ 7,000,000
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.
[2]	Virginia Power’s Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.
[3]	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2017 has been derived from the audited Consolidated Balance Sheet at that date.

Related-Party Transactions (Det

Related-Party Transactions (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Commodity purchases from affiliates		$ 139	$ 137	$ 537	$ 349
Services provided by affiliates	[1]	112	112	232	224
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Services provided to related parties		5	7	11	12
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Commodity purchases from affiliates			1	1
Services provided by affiliates	[2]	33	36	66	73
Services provided to related parties	[3]	61	36	113	75
Commodity purchases from affiliates		(2)
Other receivables	[4]	19		19		$ 12
Customer receivables from related parties						1
Affiliated notes receivable	[5]	18		18		20
Dominion Energy Gas Holdings, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Services provided to related parties		16	$ 18	34	$ 36
Imbalances receivable from affiliates						$ 1
Imbalances payable to affiliates	[6]	$ 5		$ 5
[1]	Includes capitalized expenditures of $38 million and $37 million for the three months ended June 30, 2018 and 2017, respectively, and $75 million and $71 million for the six months ended June 30, 2018 and 2017, respectively.
[2]	Includes capitalized expenditures of $7 million and $12 million for the three months ended June 30, 2018 and 2017, respectively, and $17 million and $20 million for the six months ended June 30, 2018 and 2017, respectively.
[3]	Amounts primarily attributable to Atlantic Coast Pipeline, a related-party VIE.
[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	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Related Party Transaction [Line Items]
Capital expenditures			$ 2,046	$ 2,748
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Capital expenditures			1,170	1,216
Virginia Electric and Power Company | Services provided by affiliates | Affiliated Entity
Related Party Transaction [Line Items]
Capital expenditures	$ 38	$ 37	75	71
Dominion Energy Gas Holdings, LLC
Related Party Transaction [Line Items]
Capital expenditures			316	309
Dominion Energy Gas Holdings, LLC | Services provided by affiliates | Affiliated Entity
Related Party Transaction [Line Items]
Capital expenditures	$ 7	$ 12	$ 17	$ 20

Employee Benefit Plans (Net Per

Employee Benefit Plans (Net Periodic Benefit Cost (Credit)) (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 40	$ 34	$ 79	$ 69
Interest cost	84	87	168	173
Expected return on plan assets	(168)	(161)	(333)	(320)
Amortization of prior service cost (credit)	1	1	1	1
Amortization of net actuarial loss	49	41	97	81
Settlements			0	1
Net periodic benefit cost (credit)	6	2	12	5
Pension Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	4	9	8
Interest cost	7	8	14	15
Expected return on plan assets	(38)	(36)	(75)	(71)
Amortization of prior service cost (credit)	0	0	0	0
Amortization of net actuarial loss	5	4	10	8
Net periodic benefit cost (credit)	(21)	(20)	(42)	(40)
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	6	6	13	13
Interest cost	14	14	28	30
Expected return on plan assets	(35)	(31)	(71)	(63)
Amortization of prior service cost (credit)	(13)	(13)	(26)	(25)
Amortization of net actuarial loss	2	3	5	6
Settlements			0	0
Net periodic benefit cost (credit)	(26)	(21)	(51)	(39)
Other Postretirement Benefits | Dominion Energy Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1	2	2
Interest cost	2	3	5	6
Expected return on plan assets	(6)	(6)	(14)	(12)
Amortization of prior service cost (credit)	(1)	(1)	(2)	(1)
Amortization of net actuarial loss	1	0	2	1
Net periodic benefit cost (credit)	$ (3)	$ (3)	$ (7)	$ (4)

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Detail)	6 Months Ended
	Jun. 30, 2018USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions to defined benefit pension plans and OPEB plans	$ 0
Expected contribution to voluntary employees' beneficiary association for the remainder of 2018	12,000,000
Dominion Energy Gas Holdings, LLC
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions to defined benefit pension plans and OPEB plans	0
Expected contribution to voluntary employees' beneficiary association for the remainder of 2018	$ 12,000,000

Operating Segments (Narrative)

Operating Segments (Narrative) (Detail) - Operating Segments - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting Information [Line Items]
After- tax net expenses	$ (310)	$ (1)
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After- tax net expenses	(230)
Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
After- tax net expenses	(89)
Disallowance charge	122
Disallowance charge, after tax	89
Write off of regulatory asset		15
Write off of regulatory asset, after tax		9
Virginia Regulation
Segment Reporting Information [Line Items]
Charge associated with legislation enacted	215
Charge associated with legislation enacted, after tax	160
Virginia Regulation | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Charge associated with legislation enacted	215
Charge associated with legislation enacted, after tax	160
Corporate and Other
Segment Reporting Information [Line Items]
After- tax net expenses	(349)	(10)
Corporate and Other | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After- tax net expenses	(237)	(7)
Corporate and Other | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
After- tax net expenses	(91)	$ (9)
Power Generation | Virginia Regulation
Segment Reporting Information [Line Items]
Charge associated with legislation enacted, after tax	109
Power Generation | Virginia Regulation | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Charge associated with legislation enacted, after tax	109
Power Generation | Virginia Legislation | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Asset retirement obligations	81
Asset retirement obligations, after tax	60
Power Generation | Ash Ponds and Landfills Certain Utility Generation Facility | Virginia Legislation
Segment Reporting Information [Line Items]
Asset retirement obligations	81
Asset retirement obligations, after tax	60
Power Delivery | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Customer settlement	16
Customer settlement, after tax	10
Power Delivery | Virginia Regulation
Segment Reporting Information [Line Items]
Charge associated with legislation enacted, after tax	51
Power Delivery | Virginia Regulation | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Charge associated with legislation enacted, after tax	51
Gas Infrastructure | Federal Energy Regulatory Commission
Segment Reporting Information [Line Items]
Disallowance charge	122
Disallowance charge, after tax	$ 89

Operating Segments (Schedule of

Operating Segments (Schedule of Segment Reporting Information, by Segment) (Detail) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting Information [Line Items]
Operating revenue	[1]	$ 3,088	$ 2,813	$ 6,554	$ 6,197
Net income (loss) attributable to Dominion Energy		449	390	952	1,022
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue	[2]	1,829	1,747	3,577	3,578
Net income (loss) attributable to Dominion Energy		339	318	523	674
Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating revenue	[3]	459	422	985	912
Net income (loss) attributable to Dominion Energy		15	77	181	185
Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue		(187)	(333)	(376)	(759)
Operating Segments
Segment Reporting Information [Line Items]
Operating revenue		3,088	2,813	6,554	6,197
Adjustments/Eliminations
Segment Reporting Information [Line Items]
Operating revenue		14	181	42	454
Net income (loss) attributable to Dominion Energy		0	0	0	0
Eliminations
Segment Reporting Information [Line Items]
Operating revenue		(173)	(152)	(334)	(305)
Power Delivery
Segment Reporting Information [Line Items]
Operating revenue		528	530	1,091	1,084
Net income (loss) attributable to Dominion Energy		145	127	301	252
Power Delivery | Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue		6	7	12	12
Power Delivery | Operating Segments
Segment Reporting Information [Line Items]
Operating revenue		534	537	1,103	1,096
Power Delivery | Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue		528	533	1,091	1,090
Net income (loss) attributable to Dominion Energy		145	125	299	250
Power Generation
Segment Reporting Information [Line Items]
Operating revenue		1,635	1,507	3,495	3,160
Net income (loss) attributable to Dominion Energy		276	240	624	501
Power Generation | Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue		3	2	5	5
Power Generation | Operating Segments
Segment Reporting Information [Line Items]
Operating revenue		1,638	1,509	3,500	3,165
Power Generation | Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue		1,301	1,214	2,701	2,488
Net income (loss) attributable to Dominion Energy		227	198	449	421
Gas Infrastructure
Segment Reporting Information [Line Items]
Operating revenue		914	589	2,136	1,490
Net income (loss) attributable to Dominion Energy		249	163	576	426
Gas Infrastructure | Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue		8	175	14	441
Gas Infrastructure | Operating Segments
Segment Reporting Information [Line Items]
Operating revenue		922	764	2,150	1,931
Gas Infrastructure | Operating Segments | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating revenue		459	422	985	912
Net income (loss) attributable to Dominion Energy		108	88	275	197
Corporate and Other
Segment Reporting Information [Line Items]
Operating revenue		(3)	6	(210)	9
Net income (loss) attributable to Dominion Energy		(221)	(140)	(549)	(157)
Corporate and Other | Intersegment revenue
Segment Reporting Information [Line Items]
Operating revenue		170	149	345	301
Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
Operating revenue		167	155	135	310
Corporate and Other | Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating revenue			0	(215)	0
Net income (loss) attributable to Dominion Energy		(33)	(5)	(225)	3
Corporate and Other | Operating Segments | Dominion Energy Gas Holdings, LLC
Segment Reporting Information [Line Items]
Operating revenue		0	0	0	0
Net income (loss) attributable to Dominion Energy		$ (93)	$ (11)	$ (94)	$ (12)
[1]	See Note 10 for amounts attributable to related parties.
[2]	See Note 18 for amounts attributable to affiliates.
[3]	See Note 18 for amounts attributable to related parties.