Virginia Electric & Power 10-K 24 Feb 22 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2021	Feb. 11, 2022	Jun. 30, 2021
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2021
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Document Annual Report	true
Document Transition Report	false
Entity Interactive Data Current	Yes
Entity Registrant Name	DOMINION ENERGY, INC.
Entity Central Index Key	0000715957
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 59.3
Entity File Number	001-08489
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-1229715
Entity Address, Address Line One	120 TREDEGAR STREET
Entity Address, City or Town	RICHMOND
Entity Address, Postal Zip Code	23219
City Area Code	804
Local Phone Number	819-2000
Entity Address, State or Province	VA
Entity Common Stock, Shares Outstanding		810,463,489
ICFR Auditor Attestation Flag	true
Auditor Firm ID	34
Auditor Name	Deloitte & Touche LLP
Auditor Location	Richmond, Virginia
Documents Incorporated by Reference	Portions of Dominion Energy’s 2022 Proxy Statement are incorporated by reference in Part III.
Virginia Electric and Power Company
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2021
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Document Annual Report	true
Document Transition Report	false
Entity Interactive Data Current	Yes
Entity Registrant Name	Virginia ELECTRIC AND POWER COMPANY
Entity Central Index Key	0000103682
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity File Number	000-55337
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-0418825
Entity Address, Address Line One	120 TREDEGAR STREET
Entity Address, City or Town	RICHMOND
Entity Address, Postal Zip Code	23219
City Area Code	804
Local Phone Number	819-2000
Entity Address, State or Province	VA
Entity Common Stock, Shares Outstanding		274,723
ICFR Auditor Attestation Flag	false
Auditor Firm ID	34
Auditor Name	Deloitte & Touche LLP
Auditor Location	Richmond, Virginia
Common Stock
Document Information [Line Items]
Trading Symbol	D
Title of 12(b) Security	Common Stock, no par value
Security Exchange Name	NYSE
2019 Series A Corporate Units
Document Information [Line Items]
Trading Symbol	DCUE
Title of 12(b) Security	2019 Series A Corporate Units
Security Exchange Name	NYSE

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Revenue		$ 13,964	$ 14,172	$ 14,401
Operating Expenses
Electric fuel and other energy-related purchases		2,368	2,243	2,885
Purchased (excess) capacity		70	53	88
Purchased gas		1,083	889	1,560
Other operations and maintenance		3,734	3,685	3,790
Depreciation, depletion and amortization		2,478	2,332	2,283
Other taxes		909	871	883
Impairment of assets and other charges		195	2,105	1,520
Losses (gains) on sales of assets		108	(61)	(152)
Total operating expenses		10,945	12,117	12,857
Income from operations		3,019	2,055	1,544
Earnings from equity method investees		276	40	8
Other income		1,157	693	803
Interest and related charges		1,354	1,377	1,486
Income from continuing operations including noncontrolling interests before income tax expense		3,098	1,411	869
Income tax expense		425	83	209
Net Income From Continuing Operations Including Noncontrolling Interests		2,673	1,328	660
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest	[1],[2]	641	(1,878)	716
Net Income (Loss) Including Noncontrolling Interests		3,314	(550)	1,376
Noncontrolling Interests		26	(149)	18
Net Income (Loss) Attributable to Dominion Energy		3,288	(401)	1,358
Amounts attributable to Dominion Energy
Net income from continuing operations		2,647	1,583	653
Net income (loss) from discontinued operations		$ 641	$ (1,984)	$ 705
EPS - Basic
Net income from continuing operations		$ 3.19	$ 1.83	$ 0.79
Net income (loss) discontinued operations		0.79	(2.39)	0.87
Net income (loss) attributable to Dominion Energy		3.98	(0.56)	1.66
EPS - Diluted
Net income from continuing operations		3.19	1.82	0.75
Net income (loss) discontinued operations		0.79	(2.39)	0.87
Net income (loss) attributable to Dominion Energy		$ 3.98	$ (0.57)	$ 1.62
Virginia Electric and Power Company
Operating Revenue	[3]	$ 7,470	$ 7,763	$ 8,108
Operating Expenses
Electric fuel and other energy-related purchases	[3]	1,735	1,636	2,178
Purchased (excess) capacity		24	(17)	40
Affiliated suppliers		333	314	367
Other operations and maintenance		1,460	1,472	1,376
Depreciation, depletion and amortization		1,364	1,252	1,223
Other taxes		326	327	328
Impairment of assets and other charges (benefits)		(269)	1,093	757
Total operating expenses		4,973	6,077	6,269
Income from operations		2,497	1,686	1,839
Other income		146	80	98
Interest and related charges	[3]	534	516	524
Income before income tax expense		2,109	1,250	1,413
Income tax expense		397	229	264
Net Income (Loss) Attributable to Dominion Energy		$ 1,712	$ 1,021	$ 1,149
[1]	Includes income tax expense (benefit) of $188 million, $(204) million and $142 million for the years ended December 31, 2021, 2020 and 2019, respectively
[2]	See Note 9 for amounts attributable to related parties
[3]	See Note 25 for amounts attributable to affiliates.

Consolidated Statements of In_2

Consolidated Statements of Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement [Abstract]
Income tax expense (benefit) from discontinued operations	$ 188	$ (204)	$ 142

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income (loss) including noncontrolling interests	$ 3,314	$ (550)	$ 1,376
Net income	3,288	(401)	1,358
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	15	(239)	(110)
Changes in unrealized net gains (losses) on investment securities, net tax	(7)	43	39
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	144	25	(22)
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities, net of tax	46	227	(62)
Net realized (gains) losses on investment securities	(18)	(18)	(4)
Net pension and other postretirement benefit costs, net of tax	82	37	66
Changes in other comprehensive income from equity method investees, net of tax	(3)	1
Total other comprehensive income (loss)	259	76	(93)
Comprehensive income (loss) including noncontrolling interests	3,573	(474)	1,283
Comprehensive income (loss) attributable to noncontrolling interests	26	(149)	18
Comprehensive income (loss) attributable to Dominion Energy	3,547	(325)	1,265
Virginia Electric and Power Company
Net income	1,712	1,021	1,149
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	13	(28)	(22)
Changes in unrealized net gains (losses) on investment securities, net tax	(2)	6	5
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities, net of tax	2	2	1
Net realized (gains) losses on investment securities	(2)	(3)	(1)
Total other comprehensive income (loss)	11	(23)	(17)
Comprehensive income (loss) attributable to Dominion Energy	$ 1,723	$ 998	$ 1,132

Consolidated Statements of Co_2

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net deferred losses on derivative-hedging activities, tax	$ (6)	$ 81	$ 35
Changes in unrealized net gains (losses) on investment securities, tax	7	(14)	(14)
Changes in net unrecognized pension and other postretirement benefit costs, tax	(54)	(2)	(4)
Net derivative (gains) losses-hedging activities, tax	(15)	(75)	21
Net realized (gains) losses on investment securities, tax	5	6	1
Net pension and other postretirement benefit costs, tax	(29)	(13)	(23)
Changes in other comprehensive income from equity method investees, tax	1	(1)
Virginia Electric and Power Company
Net deferred losses on derivative-hedging activities, tax	(4)	9	8
Changes in unrealized net gains (losses) on investment securities, tax		(3)	(2)
Net derivative (gains) losses-hedging activities, tax	(1)
Net realized (gains) losses on investment securities, tax	$ 1	$ 1	$ 1

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Current Assets
Cash and cash equivalents		$ 283	$ 172
Customer receivables (less allowance for doubtful accounts of $40 and $42)		2,219	2,295
Other receivables (less allowance for doubtful accounts of $4 and $3)		349	212
Inventories:
Materials and supplies		1,167	1,105
Fossil fuel		320	349
Gas stored		144	96
Margin deposit assets		678	19
Prepayments		328	309
Regulatory assets		1,492	699
Other		264	148
Current assets held for sale	[1]	25	1,482
Total current assets		7,269	6,886
Investments
Nuclear decommissioning trust funds		7,950	6,900
Investment in equity method affiliates	[2]	2,932	2,934
Other		394	404
Total investments		11,276	10,238
Property, Plant and Equipment
Property, plant and equipment		86,503	82,959
Accumulated depreciation, depletion and amortization		(26,729)	(25,111)
Total property, plant and equipment, net		59,774	57,848
Deferred Charges and Other Assets
Goodwill	[3]	7,405	7,381
Pension and other postretirement benefit assets		2,310	1,704
Intangible assets, net		784	765
Regulatory assets		8,643	9,133
Other		2,129	1,950
Total deferred charges and other assets		21,271	20,933
Total assets		99,590	95,905
Current Liabilities
Securities due within one year		841	1,937
Supplemental 364-Day credit facility borrowings			225
Short-term debt		2,314	895
Accounts payable		1,197	944
Accrued interest, payroll and taxes		1,169	1,133
Regulatory liabilities		986	809
Liability to Atlantic Coast Pipeline		113	1,052
Q-Pipe Transaction deposit			1,290
Other	[1]	2,053	1,933
Current liabilities held for sale			625
Total current liabilities		8,673	10,843
Long-Term Debt
Long-term debt		35,190	30,915
Junior subordinated notes		1,386	2,161
Other		850	881
Total long-term debt		37,426	33,957
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		6,658	5,953
Regulatory liabilities		10,713	10,187
Asset retirement obligations		5,275	5,404
Pension and other postretirement benefit liability		442	1,706
Other	[1]	1,485	1,394
Total deferred credits and other liabilities		24,573	24,644
Total liabilities		70,672	69,444
Commitments and Contingencies (see Note 23)
Preferred stock (See Note 19)		1,610
Shareholders' Equity
Preferred stock (See Note 19)		1,783	2,387
Common stock - no par	[4]	21,610	21,258
Retained earnings		5,373	4,189
Accumulated other comprehensive loss		(1,458)	(1,717)
Shareholders' equity		27,308	26,117
Noncontrolling interests			344
Total shareholders' equity		27,308	26,461
Total liabilities, mezzanine equity and shareholders' equity		99,590	95,905
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents		26	35
Customer receivables (less allowance for doubtful accounts of $40 and $42)		1,172	1,315
Other receivables (less allowance for doubtful accounts of $4 and $3)		112	91
Affiliated receivables		37	5
Inventories:
Materials and supplies		610	581
Fossil fuel		261	281
Margin deposit assets		167	1
Prepayments		37	32
Regulatory assets		850	295
Other	[5]	78	26
Total current assets		3,350	2,662
Investments
Nuclear decommissioning trust funds		3,734	3,197
Other		3	3
Total investments		3,737	3,200
Property, Plant and Equipment
Property, plant and equipment		49,890	46,736
Accumulated depreciation, depletion and amortization		(15,234)	(14,167)
Total property, plant and equipment, net		34,656	32,569
Deferred Charges and Other Assets
Pension and other postretirement benefit assets	[5]	431	354
Intangible assets, net		395	334
Regulatory assets		4,130	3,509
Other	[5]	1,233	1,026
Total deferred charges and other assets		6,189	5,223
Total assets		47,932	43,654
Current Liabilities
Securities due within one year		313	8
Short-term debt		745	45
Accounts payable		402	332
Payables to affiliates		121	266
Affiliated current borrowings		699	380
Accrued interest, payroll and taxes		274	253
Asset retirement obligations		191	166
Regulatory liabilities		647	425
Derivative liabilities	[5]	134	390
Other		567	562
Total current liabilities		4,093	2,827
Long-Term Debt
Long-term debt		13,453	13,207
Other		503	480
Total long-term debt		13,956	13,687
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		3,183	2,779
Regulatory liabilities		5,740	5,338
Asset retirement obligations		3,732	3,654
Other	[5]	1,248	812
Total deferred credits and other liabilities		13,903	12,583
Total liabilities		31,952	29,097
Commitments and Contingencies (see Note 23)
Shareholders' Equity
Common stock - no par	[6]	5,738	5,738
Other paid-in capital		1,113	1,113
Retained earnings		9,170	7,758
Accumulated other comprehensive loss		(41)	(52)
Shareholders' equity		15,980	14,557
Total liabilities, mezzanine equity and shareholders' equity		$ 47,932	$ 43,654
[1]	See Note 9 for amounts attributable to related parties .
[2]	Excludes liability to Atlantic Coast Pipeline.
[3]	Goodwill amounts do not contain any accumulated impairment losses.
[4]	1.8 billion shares authorized; 810 million shares and 806 million shares outstanding at December 31, 2021 and 2020, respectively.
[5]	See Note 25 for amounts attributable to affiliates.
[6]	500,000 shares authorized; 274,723 shares outstanding at December 31, 2021 and 2020.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Customer receivables, allowance for doubtful accounts	$ 40	$ 42
Other receivables, allowance for doubtful accounts	$ 4	$ 3
Common stock, shares authorized	1,800,000,000	1,800,000,000
Common stock, shares outstanding	810,000,000	806,000,000
Virginia Electric and Power Company
Customer receivables, allowance for doubtful accounts	$ 28	$ 23
Other receivables, allowance for doubtful accounts	$ 2	$ 2
Common stock, shares authorized	500,000	500,000
Common stock, shares outstanding	274,723	274,723

Consolidated Statements of Equi

Consolidated Statements of Equity - USD ($) $ in Millions	Total	Series A Preferred Stock	Cumulative Effect, Period of Adoption, Adjustment	Preferred Stock	Preferred StockSeries A Preferred Stock	Common Stock	Common StockSeries A Preferred Stock	Retained Earnings	Retained EarningsCumulative Effect, Period of Adoption, Adjustment	AOCI	Total Shareholders' Equity	Total Shareholders' EquitySeries A Preferred Stock	Total Shareholders' EquityCumulative Effect, Period of Adoption, Adjustment	Noncontrolling Interests
Beginning balance at Dec. 31, 2018	$ 22,048					$ 12,588		$ 9,219		$ (1,700)	$ 20,107			$ 1,941
Beginning balance (in shares) at Dec. 31, 2018						681,000,000
Accounting Standards Update [Extensible List]	Accounting Standards Update 2016-02, us-gaap:AccountingStandardsUpdate201613Member
Net income (loss) including noncontrolling interests	$ 1,376							1,358			1,358			18
Issuance of stock	$ 5,401			$ 2,387		$ 3,014					5,401
Issuance of stock (in shares)	6,100,000			2,000,000		39,000,000
Stock repurchases (in shares)						0
Stock purchase contract component of 2019 Equity Units	$ (264)					$ (264)					(264)
Acquisition of SCANA	6,818					$ 6,818					6,818
Acquisition of SCANA (in shares)						96,000,000
Acquisition of public interest in Dominion Energy Midstream	(40)					$ 1,181					1,181			(1,221)
Acquisition of public interest in Dominion Energy Midstream (in shares)						22,000,000
Sale of interest in Cove Point	1,862					$ 476					476			1,386
Stock awards (net of change in unearned compensation)	24					24					24
Preferred stock dividends (See Note 19)	(17)							(17)			(17)
Common dividends and distributions	(3,068)							(2,983)			(2,983)			(85)
Other comprehensive income (loss), net of tax	(93)									(93)	(93)
Other	(14)					(13)		(1)			(14)
Ending balance at Dec. 31, 2019	$ 34,033		$ (48)	$ 2,387		$ 23,824		7,576	$ (48)	(1,793)	31,994		$ (48)	2,039
Ending Balance (in shares) at Dec. 31, 2019				2,000,000		838,000,000
Accounting Standards Update [Extensible List]	Accounting Standards Update 2016-02
Net income (loss) including noncontrolling interests	$ (550)							(401)			(401)			(149)
Issuance of stock	481					$ 481					481
Issuance of stock (in shares)						7,000,000
Stock repurchases	(3,080)					$ (3,080)					(3,080)
Stock repurchases (in shares)						(38,900,000)
Stock awards (net of change in unearned compensation)	29					$ 29					29
Preferred stock dividends (See Note 19)	(65)							(65)			(65)
Common dividends and distributions	(3,037)							(2,873)			(2,873)			(164)
Other comprehensive income (loss), net of tax	76									76	76
GT&S Transaction closing	(1,367)					17					17			(1,384)
Other	(11)					(13)					(13)			2
Ending balance at Dec. 31, 2020	$ 26,461			$ 2,387		$ 21,258		4,189		(1,717)	26,117			344
Ending Balance (in shares) at Dec. 31, 2020				2,000,000		806,000,000
Accounting Standards Update [Extensible List]	Accounting Standards Update 2016-02
Net income (loss) including noncontrolling interests	$ 3,314							3,288			3,288			26
Issuance of stock	1,332			$ 992		$ 340					1,332
Issuance of stock (in shares)				1,000,000		4,000,000
Stock repurchases (in shares)						0
Stock awards (net of change in unearned compensation)	28					$ 28					28
Preferred stock dividends (See Note 19)	(68)							(68)			(68)
Common dividends and distributions	(2,083)							(2,036)			(2,036)			(47)
Other comprehensive income (loss), net of tax	259									259	259
Reclassification of Series A Preferred Stock to Mezzanine Equity		$ (1,610)			$ (1,596)		$ (14)					$ (1,610)
Reclassification of Series A Preferred Stock to Mezzanine Equity (in shares)					(1,000,000)
Sale of non-wholly-owned nonregulated solar facilities	(323)													$ (323)
Other	(2)					(2)					(2)
Ending balance at Dec. 31, 2021	$ 27,308			$ 1,783		$ 21,610		$ 5,373		$ (1,458)	$ 27,308
Ending Balance (in shares) at Dec. 31, 2021				2,000,000		810,000,000

Consolidated Statements of Eq_2

Consolidated Statements of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement Of Stockholders Equity [Abstract]
Dividends declared per common share	$ 2.52	$ 3.45	$ 3.67

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Activities
Net income (loss) including noncontrolling interests	$ 3,314	$ (550)	$ 1,376
Net income	3,288	(401)	1,358
Adjustments to reconcile net income (loss) including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	2,768	2,836	2,977
Deferred income taxes and investment tax credits	487	(324)	216
Gain from sale of Q-Pipe Group and GT&S Transaction	(685)	(134)
Contribution to pension plan		(250)	(21)
Net loss on sale of interest in renewable generation facilities	211
Provision for refunds and rate credits to electric utility customers	356		800
Impairment of assets and other charges	182	2,345	1,333
Loss from investment in Atlantic Coast Pipeline	20	2,405
Charges related to a voluntary retirement program			320
Gains on sales of assets and equity method investments	(97)	(63)	(167)
Net (gains) losses on nuclear decommissioning trusts funds and other investments	(639)	(412)	(626)
Charge (revision) for future ash pond and landfill closure costs		11	(113)
Other adjustments	294	213	29
Changes in:
Accounts receivable	(183)	(292)	(105)
Inventories	(74)	39	(90)
Deferred fuel and purchased gas costs, net	(939)	212	195
Prepayments	(20)	7	(225)
Accounts payable	156	35	(225)
Accrued interest, payroll and taxes	41	(53)	(78)
Customer deposits	(24)	(13)	(101)
Margin deposit assets and liabilities	(664)	26	60
Net realized and unrealized changes related to derivative activities	435	(36)	43
Pension and other postretirement benefits	(314)	(319)	(148)
Other operating assets and liabilities	(588)	(456)	(246)
Net cash provided by operating activities	4,037	5,227	5,204
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(5,960)	(6,020)	(4,980)
Cash and restricted cash acquired in the SCANA Combination			389
Acquisition of solar development projects	(101)	(311)	(341)
Proceeds from GT&S Transaction and sale of Q-Pipe Group	1,522	3,687
Repayment of Q-Pipe Transaction deposit	(1,265)
Proceeds from sale of non-wholly-owned nonregulated solar facilities	495
Proceeds from sales of securities	3,985	4,278	1,712
Purchases of securities	(3,939)	(4,379)	(1,749)
Proceeds from sales of assets and equity method investments	159	143	447
Contributions to equity method affiliates	(1,021)	(148)	(209)
Acquisition of equity method investments		(178)
Other	(122)	12	109
Net cash used in investing activities	(6,247)	(2,916)	(4,622)
Financing Activities
Issuance (repayment) of short-term debt, net	1,419	(16)	404
Issuance of short-term notes	1,265	1,125	3,000
Repayment and repurchase of short-term notes	(1,265)	(1,125)	(3,000)
Supplemental 364-day credit facility borrowings		225
Supplemental 364-day credit facility repayments	(225)
Credit facility borrowings (repayments)			(113)
Issuance and remarketing of long-term debt	6,400	6,577	4,374
Repayment and repurchase of long-term debt (including redemption premiums)	(3,750)	(2,879)	(9,116)
Proceeds from sale of interest in Cove Point			2,078
Issuance of 2019 Equity Units			1,582
Supplemental credit facility borrowings	900
Supplemental credit facility repayments	(900)
Issuance of preferred stock	742		791
Issuance of common stock	192	159	2,515
Repurchase of common stock		(3,080)
Common dividend payments	(2,036)	(2,873)	(2,983)
Other	(371)	(446)	(236)
Net cash provided by (used in) financing activities	2,371	(2,333)	(704)
Increase (decrease) in cash, restricted cash and equivalents	161	(22)	(122)
Cash, restricted cash and equivalents at beginning of period	247	269	391
Cash, restricted cash and equivalents at end of period	408	247	269
Virginia Electric and Power Company
Operating Activities
Net income	1,712	1,021	1,149
Adjustments to reconcile net income (loss) including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)	1,521	1,421	1,392
Deferred income taxes and investment tax credits	343	(206)	(80)
Impairment of assets and other charges	(269)	1,079	624
Charges related to a voluntary retirement program			116
Charge (revision) for future ash pond and landfill closure costs		11	(113)
Provision for refunds to customers	356
Other adjustments	19	(61)	(63)
Changes in:
Accounts receivable	(112)	(266)	(219)
Affiliated receivables and payables	(175)	78	75
Inventories	(10)	10	(56)
Deferred fuel and purchased gas costs, net	(652)	131	243
Prepayments	(4)	(5)	1
Accounts payable	19	6	(31)
Accrued interest, payroll and taxes	21	(4)	5
Margin deposit assets and liabilities	(166)	(1)
Net realized and unrealized changes related to derivative activities		(6)	21
Other operating assets and liabilities	(106)	(308)	(280)
Net cash provided by operating activities	2,497	2,900	2,784
Investing Activities
Plant construction and other property additions	(3,521)	(3,138)	(2,642)
Purchases of nuclear fuel	(160)	(199)	(157)
Acquisition of solar development projects	(75)	(35)	(182)
Proceeds from sales of securities	1,791	884	858
Purchases of securities	(1,789)	(936)	(905)
Other		21	(37)
Net cash used in investing activities	(3,754)	(3,403)	(3,065)
Financing Activities
Repayment of short-term debt, net	700	(198)	(71)
Issuance (repayment) of affiliated current borrowings, net	319	273	(117)
Issuance and remarketing of long-term debt	1,000	1,327	1,248
Repayment and repurchase of long-term debt (including redemption premiums)	(450)	(427)	(591)
Common dividend payments	(300)	(430)	(190)
Other	(21)	(31)	(12)
Net cash provided by (used in) financing activities	1,248	514	267
Increase (decrease) in cash, restricted cash and equivalents	(9)	11	(14)
Cash, restricted cash and equivalents at beginning of period	35	24	38
Cash, restricted cash and equivalents at end of period	$ 26	$ 35	$ 24

Virginia Electric and Power Com

Virginia Electric and Power Company Consolidated Statements of Common Shareholder's Equity - USD ($) shares in Thousands, $ in Millions	Total	Common Stock	AOCI	Virginia Electric and Power Company	Virginia Electric and Power CompanyCommon Stock	Virginia Electric and Power CompanyOther Paid-In Capital	Virginia Electric and Power CompanyRetained Earnings	Virginia Electric and Power CompanyAOCI
Beginning balance at Dec. 31, 2018				$ 13,047	$ 5,738	$ 1,113	$ 6,208	$ (12)
Beginning balance (in shares) at Dec. 31, 2018		681,000			275
Net income	$ 1,358			1,149			1,149
Dividends				(190)			(190)
Other comprehensive income (loss), net of tax	(93)		$ (93)	(17)				(17)
Ending balance at Dec. 31, 2019			(1,793)	13,989	$ 5,738	1,113	7,167	(29)
Ending Balance (in shares) at Dec. 31, 2019		838,000			275
Net income	(401)			1,021			1,021
Dividends				(430)			(430)
Other comprehensive income (loss), net of tax	76		76	(23)				(23)
Ending balance at Dec. 31, 2020	26,117		(1,717)	14,557	$ 5,738	1,113	7,758	(52)
Ending Balance (in shares) at Dec. 31, 2020		806,000			275
Net income	3,288			1,712			1,712
Dividends				(300)			(300)
Other comprehensive income (loss), net of tax	259		259	11				11
Ending balance at Dec. 31, 2021	$ 27,308		$ (1,458)	$ 15,980	$ 5,738	$ 1,113	$ 9,170	$ (41)
Ending Balance (in shares) at Dec. 31, 2021		810,000			275

Nature of Operations

Nature of Operations	12 Months Ended
	Dec. 31, 2021
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 distributors of energy. Dominion Energy’s operations are conducted through various subsidiaries, including Virginia Power. Dominion Energy’s operations also include DESC, regulated gas distribution operations primarily in the eastern and Rocky Mountain regions of the U.S., nonregulated electric generation and, following the completion of the GT&S Transaction in November 2020, a noncontrolling interest in Cove Point. See Note 3 for a description of the sale of substantially all of Dominion Energy’s gas transmission and storage operations through the GT&S Transaction completed in November 2020 and the sale of the Q-Pipe Group completed in December 2021. Dominion Energy manages its daily operations through four primary operating segments: Dominion Energy Virginia, Gas Distribution, Dominion Energy South Carolina and Contracted Assets. Dominion Energy also reports a Corporate and Other segment, which includes its corporate, service company and other functions (including unallocated debt) as well as Dominion Energy’s noncontrolling interest in Wrangler. 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 operating segments’ performance or in allocating resources. In addition, Corporate and Other includes the net impact of discontinued operations consisting of Dominion Energy’s gas transmission and storage operations as discussed in Note 3 and its equity investment in Atlantic Coast Pipeline as discussed in Note 9. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Virginia Power is a member of PJM, an RTO, and its electric transmission facilities are integrated into the PJM wholesale electricity markets. All of Virginia Power’s stock is owned by Dominion Energy. Virginia Power manages its daily operations through one primary operating segment: Dominion Energy Virginia. It also reports a Corporate and Other segment that primarily includes specific items attributable to its operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance or in allocating resources. See Note 26 for further discussion of the Companies’ operating segments.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Significant Accounting Policies	NOTE 2. SIGNIFICANT ACCOUNTING POLICIES General The Companies make certain estimates and assumptions in preparing their Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses and cash flows for the periods presented. Actual results may differ from those estimates. The Companies’ Consolidated Financial Statements include, after eliminating intercompany transactions and balances, 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. Clearway’s ownership interest in Four Brothers and Three Cedars (through December 2021), Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy nonregulated solar projects (through December 2021), Brookfield’s 25% interest in Cove Point (effective December 2019 until November 2020) and the non-Dominion Energy held interest in Dominion Energy Midstream (through January 2019) are reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. The Companies report certain contracts, instruments and investments at fair value. See Note 6 for further information on fair value measurements. The Companies consider acquisitions or dispositions in which substantially all of the fair value of the gross assets acquired or disposed of is concentrated into a single identifiable asset or group of similar identifiable assets to be an acquisition or a disposition of an asset, rather than a business. See Notes 3 and 10 for further information on such transactions. Dominion Energy maintains pension and other postretirement benefit plans and Virginia Power participates in certain of these plans. See Note 22 for further information on these plans. Certain amounts in the Companies’ 2020 and 2019 Consolidated Financial Statements and Notes have been reclassified to conform to the 2021 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows. Effective in the second quarter of 2021, the Companies updated their Statements of Cash Flows to present net charges for allowance for credit risk and write-offs of accounts receivables within other adjustments to reconcile net income to net cash provided by operating activities from the previous presentation within changes in accounts receivable. All prior period information has been conformed to this presentation, which does not result in a change to net cash provided by operating activities. Amounts disclosed for Dominion Energy are inclusive of Virginia Power, where applicable. Operating Revenue Operating revenue is recorded on the basis of services rendered, commodities delivered, or contracts settled and includes amounts yet to be billed to customers. The Companies collect sales, consumption and consumer utility taxes; however, these amounts are excluded from revenue. Dominion Energy’s customer receivables at December 31, 2021 and 2020 included $779 million and $1.1 billion, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power’s customer receivables at December 31, 2021 and 2020 included $398 million and $740 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. See Note 25 for amounts attributable to related parties. The primary types of sales and service activities reported as operating revenue for Dominion Energy 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 and sales to Virginia Power customers from non-jurisdictional solar generation facilities; • 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 state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers, sales of gathering services and sales of transportation services to off-system customers; • 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 sales of commodities related to nonregulated extraction activities and other miscellaneous products. Other nonregulated revenue also includes sales of energy-related products and services from Dominion Energy’s retail energy marketing operations (through December 2021), service concession arrangements and revenue associated with services provided to entities presented in discontinued operations under transition services agreements. 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 Virginia Power 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 consists of sales to customers from non-jurisdictional solar generation facilities; • 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 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, gains and losses from derivative instruments not subject to hedge accounting and lease revenues. The Companies record refunds to customers as required by state commissions as a reduction to regulated electric sales or regulated gas sales, as applicable. The Companies’ revenue accounted for under the alternative revenue program guidance primarily consists of the equity return for under-recovery of certain riders. Alternative revenue programs compensate the Companies for certain projects and initiatives. Revenues arising from these programs are presented separately from revenue arising from contracts with customers in the categories above. Revenues from electric and gas sales are recognized over time, as the customers of the Companies consume gas and electricity as it is delivered. 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 has 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 and services typically transfer control and are recognized as revenue upon delivery of the product or service. 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. Operating revenue for the gas transmission and storage operations sold to BHE as part of the GT&S Transaction and sold to Southwest Gas as part of the Q-Pipe Group sale primarily consisted of FERC-regulated sales of transmission and storage services, LNG terminalling services, sales of extracted products and associated hedging activities and NGL activities, including gathering and processing and sales of production and condensate as well as services performed for Atlantic Coast Pipeline. This revenue is included in discontinued operations in Dominion Energy’s Consolidated Statements of Income. Transportation and storage contracts associated with the operations sold to BHE as part of the GT&S Transaction and sold to Southwest Gas as part of the Q-Pipe Group sale were primarily stand-ready service contracts that include fixed reservation and variable usage fees. LNG terminalling services, included in discontinued operations, are also stand-ready service contracts, primarily consisting of fixed fees, offset by service credits associated with the start-up phase of the Liquefaction Facility. NGLs received during natural gas processing are recorded in discontinued operations at fair value as service revenue recognized over time, and revenue continued to be recognized from the subsequent sale of the NGLs to customers upon delivery. Credit Risk Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction. The Companies maintain a provision for credit losses based on factors surrounding the credit risk of their customers, historical trends and other information. Effective January 2020, expected credit losses are estimated and recorded based on historical experience, current conditions and reasonable and supportable forecasts that affect the collectability of financial assets held at amortized cost as well as expected credit losses on commitments with respect to financial guarantees. Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs Where permitted by regulatory authorities, the differences between the Companies’ actual electric fuel and purchased energy expenses and Dominion Energy’s purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability. Of the cost of fuel used in electric generation and energy purchases to serve Virginia utility customers, at December 31, 2021, approximately 86% is subject to Virginia Power’s deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms. Of the cost of fuel used in electric generation and energy purchases to serve South Carolina utility customers, at December 31, 2021, approximately 96% is subject to DESC’s deferred fuel accounting. Virtually all of East Ohio, Questar Gas, Hope, DESC and PSNC’s natural gas purchases are either subject to deferral accounting or are recovered from the customer in the same accounting period as the sale. Income Taxes A consolidated federal income tax return is filed for Dominion Energy and its subsidiaries, including Virginia Power. In addition, where applicable, combined income tax returns for Dominion Energy and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Virginia Power participates in intercompany tax sharing agreements with Dominion Energy and its subsidiaries. Current income taxes are based on taxable income or loss and credits determined on a separate company basis. Under the agreements, if a subsidiary incurs a tax loss or earns a credit, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or credit or to the extent the tax loss or credit is absorbed by the taxable income of other Dominion Energy consolidated group members. Otherwise, the net operating loss or credit is carried forward and is recognized as a deferred tax asset until realized. Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Accordingly, deferred taxes are recognized for the future consequences of different treatments used for the reporting of transactions in financial accounting and income tax returns. The Companies establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities. The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information. If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the Consolidated Balance Sheets and current payables are included in accrued interest, payroll and taxes on the Consolidated Balance Sheets. The Companies recognize interest on underpayments and overpayments of income taxes in interest expense and other income, respectively. Penalties are also recognized in other income. In 2021, Dominion Energy reflected a $21 million benefit from the reversal of interest expense and a $7 million benefit from the reversal of penalty expense on uncertain tax positions that were effectively settled. At December 31, 2021, Virginia Power had an income tax-related affiliated receivable of $35 million, comprised of $33 million of federal income taxes and $2 million of state income taxes receivable from Dominion Energy. These affiliated balances are expected to be received from Dominion Energy. At December 31, 2020, Virginia Power had an income tax-related affiliated payable of $19 million, comprised of $17 million of federal income taxes and $2 million of state income taxes due to Dominion Energy. Virginia Power’s net affiliated balances were paid to Dominion Energy. Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold. Cash, Restricted Cash and Equivalents Cash, restricted cash and equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less. Current banking arrangements generally do not require checks to be funded until they are presented for payment. The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies: At December 2021 2020 (millions) Dominion Energy $ 70 $ 50 Virginia Power 15 30 Restricted Cash and Equivalents The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for litigation settlements, customer deposits, federal assistance funds and future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements (through December 2021), on DECP Holdings’ term loan agreement and on Eagle Solar’s senior note agreement. The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2021, 2020 and 2019: Cash, Restricted Cash and Equivalents at End/Beginning of Year December 31, 2021 December 31, 2020 December 31, 2019 December 31, 2018 (millions) Dominion Energy Cash and cash equivalents (1) $ 283 $ 179 $ 166 $ 268 Restricted cash and equivalents (2)(3) 125 68 103 123 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 408 $ 247 $ 269 $ 391 Virginia Power Cash and cash equivalents $ 26 $ 35 $ 17 $ 29 Restricted cash and equivalents (3) — — 7 9 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 26 $ 35 $ 24 $ 38 (1) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $7 million, $31 million and $110 million of cash and cash equivalents included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (2) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $3 million, $12 million and $89 million of restricted cash included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (3) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets. Supplemental Cash Flow Information The following table provides supplemental disclosure of cash flow information related to Dominion Energy: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 1,340 $ 1,519 $ 1,643 Income taxes 160 292 106 Significant noncash investing and financing activities: (1)(2)(3)(4)(5) Accrued capital expenditures 637 485 555 Leases (6) 96 173 157 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 3 for noncash investing and financing activities related to the SCANA Combination. (3) See Note 5 for noncash activities related to the sale of a noncontrolling interest in Cove Point. (4) See Note 9 for noncash investing activities related to the acquisition of a noncontrolling interest in Wrangler. (5) See Notes 18,19 and 20 for noncash financing activities related to the acquisition of the public interest in Dominion Energy Midstream, the remarketing of RSNs, the issuance of stock purchase contracts associated with the 2019 Equity Units, the contribution of stock to Dominion Energy’s qualified defined benefit pension plan, derivative restructuring and the issuance of common stock associated with the settlement of litigation. See Note 23 for non-cash investing activities related to property, plant and equipment conveyed to satisfy litigation. (6) Includes $47 million of finance leases and $49 million of operating leases entered in 2021, $46 million of finance leases and $127 million of operating leases entered in 2020 and $113 million of finance leases and $44 million of operating leases entered in 2019. The following table provides supplemental disclosure of cash flow information related to Virginia Power: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 501 $ 491 $ 495 Income taxes 109 452 272 Significant noncash investing activities: (1)(2) Accrued capital expenditures 363 262 292 Leases (3) 79 32 55 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 18 for non-cash financing activities related to derivative restructuring. (3) Includes $37 million of finance leases and $42 million of operating leases entered in 2021, $32 million of finance leases entered in, 2020 and $20 million of finance leases and $35 million of operating leases entered in 2019. Distributions from Equity Method Investees Dominion Energy holds investments that are accounted for under the equity method of accounting and classifies 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. Derivative Instruments The Companies are exposed to the impact of market fluctuations in the price of electricity, natural gas and other energy-related products they market and purchase, as well as interest rate and foreign currency exchange rate risks All derivatives, except those for which an exception applies, are required to be reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. The Companies do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion Energy had margin assets of $678 To manage price and interest rate risk, the Companies hold derivative instruments that are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices or interest rates . All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses, interest and related charges or discontinued operations based on the nature of the underlying risk. Changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings. Derivative Instruments Designated as Hedging Instruments In accordance with accounting guidance pertaining to derivatives and hedge accounting, the Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For derivative instruments that are accounted for as cash flow hedges or fair value hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows. Cash Flow Hedges A majority of the Companies’ hedge strategies represents cash flow hedges of the variable price risk primarily associated with the use of interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which the Companies are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item, or as appropriate to regulatory assets or regulatory liabilities. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable. Fair Value Hedges Dominion Energy has also designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item’s fair value. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting. Property, Plant and Equipment Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred. In 2021, 2020 and 2019, Dominion Energy capitalized interest costs and AFUDC to property, plant and equipment of $117 million, $103 million and $78 million, respectively. In 2021, 2020 and 2019, Virginia Power capitalized AFUDC to property, plant and equipment of $78 million, $60 million and $34 million, respectively. Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2021, 2020 and 2019, Virginia Power recorded $35 million, $11 million and $11 million of AFUDC related to these projects, respectively. For property subject to cost-of-service rate regulation, including the Companies’ electric distribution, electric transmission and generation property and Dominion Energy’s natural gas distribution property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be abandoned and recorded as a regulatory asset for amounts expected to be collected through future rates. In 2020 and 2019, the Companies had the following charges, primarily recorded in impairment of assets and other charges in the Consolidated Statements of Income (reflected in the Corporate and Other segment), related to early retirements: • In March 2020, Virginia Power committed to retire certain coal- and oil-fired generating units before the end of their useful lives based on economic and other factors, including but not limited to market power prices and the VCEA. These units will be retired after they meet their capacity obligations to PJM in 2023. As a result, Virginia Power recorded a charge of $ million ($ million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. In addition, see Note 13 for information on the settlement of the 2021 Triennial Review. Also in 2020, Virginia Power recorded charges of $ 54 million ($ 40 million after-tax) associated with dismantling certain of these electric generation facilities. • In January 2019, Virginia Power committed to a plan to retire certain automated metering reading infrastructure associated with its electric operations before the end of its estimated useful life and replace such equipment with more current AMI technology. As a result, Virginia Power recorded a charge of $160 million ($119 million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. • In March 2019, Virginia Power committed to retire certain electric generating units before the end of their useful lives and completed the retirement of certain units at six facilities representing 1,292 MW of electric generating capacity, which had previously been placed in cold reserve. An additional unit at Possum Point power station was retired after meeting its capacity obligation to PJM in December 2020. As a result, Virginia Power recorded a charge of $346 million ($257 million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. In addition, see Note 13 for information on the settlement of the 2021 Triennial Review. • In May 2019, Virginia Power abandoned a coal rail project at its Mt. Storm generating facility. As a result, Virginia Power recorded a charge of $62 million ($46 million after-tax). • In September 2019, the Companies abandoned certain property, plant and equipment before the end of its useful life. As a result, Dominion Energy recorded a charge of $26 million ($19 million after-tax) and Virginia Power recorded a charge of $17 million ($12 million after-tax). For property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property’s net book value at the retirement date. Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. The Companies’ average composite depreciation rates on utility property, plant and equipment are as follows: Year Ended December 2021 2020 2019 (percent) Dominion Energy (1) Generation 2.63 2.51 2.84 Transmission 2.47 2.48 2.50 Distribution 2.76 2.76 2.80 Storage 1.79 1.59 1.49 General and other 3.85 4.35 3.99 Virginia Power Generation 2.69 2.52 2.94 Transmission 2.51 2.52 2.54 Distribution 3.18 3.19 3.14 General and other 5.08 5.09 4.40 (1) Excludes rates for depreciation reported as discontinued operations. In 2020, Virginia Power updated depreciation rates for its nuclear plants to reflect lower depreciation rates as a result of expected approval of license extensions from the NRC. For the year ended December 31, 2020, this adjustment resulted in a decrease of $31 million ($23 million after-tax) in depreciation expense in Virginia Power’s Consolidated Statements of Income and an increase to Dominion Energy’s EPS of $0.03 per share. In January 2022, Dominion Energy revised the est

Acquisitions and Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2021
Text Block [Abstract]
Acquisitions and Dispositions	NOTE 3. ACQUISITIONS AND DISPOSITIONS Dominion Energy Disposition of Gas Transmission & Storage Operations In July 2020, Dominion Energy entered into an agreement with BHE with a total value of approximately $10 billion, comprised of approximately $4.0 billion of cash consideration (subject to customary closing adjustments) plus the assumption of long-term debt, to sell substantially all of its gas transmission and storage operations, including processing assets, as well as noncontrolling partnership interests in Iroquois, JAX LNG and White River Hub and a controlling interest in Cove Point (consisting of 100% of the general partner interest and 25% of the total limited partner interests). The agreement provides that Dominion Energy retains the assets and obligations of the pension and other postretirement employee benefit plans associated with the operations included in the transaction and relating to services provided through closing. In October 2020, pursuant to a provision in the agreement with BHE, Dominion Energy elected to exclude the Q-Pipe Group and certain other affiliated entities from the transaction as approval under the Hart-Scott-Rodino Act had not been obtained by mid-September 2020. Concurrently in October 2020, Dominion Energy and BHE entered into a separate agreement under which Dominion Energy would sell the Q-Pipe Group and certain other affiliated entities to BHE for cash consideration of $1.3 billion and the assumption of related long-term debt. In November 2020, Dominion Energy completed the GT&S Transaction and received cash proceeds of $2.7 billion. This transaction was structured as an asset sale for tax purposes. Dominion Energy retained a 50% noncontrolling interest in Cove Point that is accounted for as an equity method investment upon closing of the GT&S Transaction as Dominion Energy has the ability to exercise significant influence over, but not control, Cove Point. The retained 50% noncontrolling interest in Cove Point was recognized at its initial fair value of $2.8 billion on the date of close estimated using an income approach and a market approach. The valuation is considered a Level 3 fair value measurement due to the use of significant judgment and unobservable inputs, including projected timing and amount of future cash flows and a discount rate reflecting risks inherent in the future cash flows and market prices. In connection with closing of the GT&S Transaction, Dominion Energy and BHE entered into a transition services agreement under which Dominion Energy will continue to provide specified administrative services to support the operations of the disposed business for up to 24 months after closing, subsequently extended through June 2023 for certain services. In addition, BHE will provide certain administrative services to Dominion Energy. Dominion Energy recorded revenue of $21 million and $4 million associated with the transition service agreement in operating revenue in the Consolidated Statements of Income for the years ended December 31, 2021 and 2020, respectively. Also in November 2020, BHE provided a $1.3 billion deposit to Dominion Energy on the Q-Pipe Transaction. In July 2021, Dominion Energy and BHE mutually agreed to terminate the Q-Pipe Transaction as a result of uncertainty associated with receiving approval under the Hart-Scott-Rodino Act. Also in July 2021, Dominion Energy entered into an approximately $1.3 billion term loan credit agreement and borrowed the full amount available thereunder. The agreement matured in December 2021 and bore interest at a variable rate. The proceeds were utilized to repay the deposit received from BHE on the Q-Pipe Transaction. Upon completion of a sale of the Q-Pipe Group, Dominion Energy was required to utilize the net proceeds to repay any outstanding balances under the term loan agreement. In October 2021, Dominion Energy entered into an agreement with Southwest Gas to sell the Q-Pipe Group. The total value of this transaction is approximately $2 billion, comprised of approximately $1.5 billion of cash consideration (subject to customary closing adjustments) plus the assumption of long-term debt. The agreement provides that Dominion Energy retains the assets and obligations of the pension and other postretirement employee benefit plans associated with the operations included in the transaction and relating to services provided through closing. In December 2021, Dominion Energy completed the sale of the Q-Pipe Group and received cash proceeds of $1.5 billion. This transaction is structured as an asset sale for tax purposes. Upon closing, Dominion Energy recognized a gain of $666 million (net of a $191 million In connection with the closing of the sale of the Q-Pipe Group, Dominion Energy and Southwest Gas entered into a transition services agreement under which Dominion Energy will continue to provide specified administrative services to support the operations of the disposed businesses for up to 12 months after closing, subject to extension. The operations included in both the GT&S Transaction and the Q-Pipe Group are presented in held-for-sale and discontinued operations effective July 2020. As a result, the previously reported amounts have been recast to reflect this presentation and depreciation and amortization ceased on the applicable assets. As Cove Point had previously been consolidated within Dominion Energy’s financial statements, balances associated with Cove Point prior to the closing of the GT&S Transaction are presented within held-for-sale and discontinued operations. See Note 9 for further information regarding Dominion Energy’s equity method investment in Cove Point. The following table represents selected information regarding the results of operations, which are reported within discontinued operations in Dominion Energy’s Consolidated Statements of Income: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 Q-Pipe Group (1) GT&S Transaction (1) Q-Pipe Group GT&S Transaction Q-Pipe Group (millions) Operating revenue $ 254 $ 1,710 $ 246 $ 2,213 $ 251 Operating expense (2) 76 1,289 96 1,367 131 Other income (loss) (3) 28 88 1 58 4 Interest and related charges (4) 25 372 20 267 20 Income before income taxes 181 137 131 637 104 Income tax expense (benefit) (5) 36 334 (9 ) 120 23 Net income (loss) including noncontrolling interests 145 (197 ) 140 517 81 Noncontrolling interests — 106 — 11 — Net income (loss) attributable to Dominion Energy $ 145 $ (303 ) $ 140 $ 506 $ 81 (1) Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date. (2) GT&S Transaction includes a charge of $482 million ($359 million after-tax) recorded in the second quarter of 2020 associated with the probable abandonment of a significant portion of the Supply Header Project as well as the establishment of a $75 million ARO as a result of the cancellation of the Atlantic Coast Pipeline Project. ( 3 ) Q-Pipe Group includes a $25 million benefit associated with the termination of the Q-Pipe Transaction in the third quarter of 2021. (4) GT&S Transaction includes a loss of $237 million ($178 million after-tax) recorded in the third quarter of 2020 associated with cash flow hedges of debt-related items that were determined to be probable of not occurring. (5) Excludes $17 million income tax benefit recorded in 2021 associated with the GT&S Transaction. The carrying amounts of major classes of assets and liabilities relating to the Q-Pipe Group, all of which was classified as current and reported as held for sale in Dominion Energy’s Consolidated Balance Sheets at December 31, 2020, were as follows: (millions) Current assets (1) $ 47 Equity method investments (2) 35 Property, plant and equipment, net 1,113 Other deferred charges and other assets, including goodwill (3) 224 Current liabilities 30 Long-term debt 426 Other deferred credits and liabilities 154 (1) Includes cash and cash equivalents of $7 million. ( 2 ) Comprised of equity method investment in White River Hub. ( 3 ) Includes goodwill of $191 million. Capital expenditures and significant noncash items relating to the disposal groups included the following: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 Q-Pipe Group (1) GT&S Transaction (1) Q-Pipe Group GT&S Transaction Q-Pipe Group (millions) Capital expenditures $ 34 $ 292 $ 38 $ 386 $ 42 Significant noncash items Impairment of assets and other charges — 469 — 13 1 Charge related to a voluntary retirement program — — — 19 3 Depreciation, depletion and amortization — 177 27 322 51 Accrued capital expenditures — — 1 25 2 (1) Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date. In October 2020, Dominion Energy settled various derivatives related to, but not included in, the GT&S Transaction for a payment of $165 million. Acquisition of SCANA In January 2019, Dominion Energy issued 95.6 million shares of Dominion Energy common stock, valued at $6.8 billion, representing 0.6690 of a share of Dominion Energy common stock for each share of SCANA common stock, in connection with the completion of the SCANA Combination. SCANA, through its regulated subsidiaries, is primarily engaged in the generation, transmission and distribution of electricity in the central, southern and southwestern portions of South Carolina and in the distribution of natural gas in North Carolina and South Carolina. In addition, at the closing of the SCANA Combination, SCANA marketed natural gas to retail customers in the southeast U.S. Following completion of the SCANA Combination, SCANA operates as a wholly-owned subsidiary of Dominion Energy. In addition, SCANA’s debt totaled $6.9 billion at closing. The SCANA Combination expanded Dominion Energy’s portfolio of regulated electric generation, transmission and distribution and regulated natural gas distribution infrastructure operations. Merger Conditions Refunds to Customers As a condition to the SCANA Merger Approval Order, DESC will provide refunds and restitution of $2.0 billion over 20 years with capital support from Dominion Energy. In September and October 2017, DESC received proceeds totaling $1.1 billion in full satisfaction of its share of a settlement agreement among DESC, Santee Cooper and Toshiba Corporation in connection with Westinghouse and WECTEC, both wholly-owned subsidiaries of Toshiba Corporation and responsible for the engineering and construction of the NND Project, filing for bankruptcy. The purchase price allocation below includes a previously established regulatory liability at DESC totaling $1.1 billion, of which $67 million was considered current, associated with the monetization of the bankruptcy settlement with Toshiba Corporation. In accordance with the terms of the SCANA Merger Approval Order, this regulatory liability, net of amounts that may be required to satisfy any liens against NND Project property, totaling $1.0 billion will be refunded to DESC electric service customers over a 20-year period ending in 2039. Additionally, in the first quarter of 2019, DESC recorded a reduction in operating revenue and a corresponding regulatory liability of $1.0 billion, of which $137 million was considered current, representing a refund of amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period, effective February 2019. As a result, Dominion Energy’s Consolidated Statements of Income for the year ended December 31, 2019 includes a $756 million after-tax charge which is reflected in the Corporate and Other segment. NND Project As a condition to the SCANA Merger Approval Order, DESC committed to excluding from rate recovery $2.4 billion of costs related to the NND Project and $180 million of costs associated with the purchase of the Columbia Energy Center power station. The remaining regulatory asset associated with the NND Project of $2.8 billion, of which $138 million was considered current, will be collected over a 20-year period, including a return on investment. In January 2019, DESC filed the capital cost rider in accordance with the terms of the SCANA Merger Approval Order for rates effective in February 2019 for DESC’s retail electric customers. The South Carolina Commission approved this filing in January 2019. Other Terms and Conditions • DESC agreed not to file an application for a general rate case with the South Carolina Commission with a requested effective date earlier than January 2021. See Note 13 for information on the status of DESC’s base rate case; • PSNC agreed not to file an application for a general rate case with the North Carolina Commission any earlier than April 2021. See Note 13 for information on the status of PSNC’s general rate case; • Dominion Energy committed to increasing SCANA’s historical level of corporate contributions to charities by $1 million per year over five years beginning in 2019; • Dominion Energy will maintain DESC and PSNC’s headquarters in Cayce, South Carolina and Gastonia, North Carolina, respectively; and • Dominion Energy will seek to minimize reductions in local employment by allowing some DES employees supporting shared and common services functions and activities to be located in Cayce, South Carolina where it makes economic and practical sense to do so. Purchase Price Allocation SCANA’s assets acquired and liabilities assumed have been measured at estimated fair value at closing and are included in Dominion Energy South Carolina and Gas Distribution. The majority of the operations acquired are subject to the rate setting authority of FERC and the North and South Carolina Commissions and are therefore accounted for pursuant to ASC 980, Regulated Operations The fair value of SCANA’s assets acquired and liabilities assumed that are not subject to the rate-setting provisions discussed above and the fair values of SCANA’s investments accounted for under the equity method were determined using the income approach and the market approach. The valuation of SCANA’s long-term debt is considered a Level 2 fair value measurement. All other valuations are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in the future market prices. The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed was reflected as goodwill. The goodwill reflects the value associated with enhancing Dominion Energy’s portfolio of regulated operations in the growing southeast region of the U.S. The goodwill recognized is not deductible for income tax purposes, and as such, no deferred taxes have been recorded related to goodwill. The table below shows the allocation of the purchase price to the assets acquired and liabilities assumed at closing, which reflects certain adjustments related to income taxes, as discussed in Note 5, from the preliminary valuation recognized during the measurement period. Amount (millions) Total current assets (1) $ 1,782 Investments (2) 224 Property, plant and equipment (3)(4) 11,006 Goodwill 2,609 Regulatory assets (5) 3,940 Other deferred charges and other assets, including intangible assets (6) 430 Total Assets 19,991 Total current liabilities (7) 1,556 Long-term debt 6,707 Deferred income taxes 1,068 Regulatory liabilities 2,706 Other deferred credits and other liabilities (8) 1,115 Total Liabilities 13,152 Total purchase price (9) $ 6,839 (1) Includes $389 million of cash, restricted cash and equivalents, of which $115 million is considered restricted. (2) Includes $31 million for equity method investments. The fair value adjustment on the equity method investments is considered to be equity method goodwill and is not amortized. (3) Includes $105 million of certain property, plant and equipment associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. As a result, Dominion Energy’s Consolidated Statements of Income for the year ended December 31, 2019 include a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges (reflected in the Corporate and Other segment). (4) Nonregulated property, plant and equipment, excluding land, will be depreciated on a straight-line basis over the remaining useful lives of such property, primarily ranging from 5 to 78 years. (5) Includes $258 million of certain income tax-related regulatory assets associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. See Note 5 for additional information. (6) Intangible assets have an estimated weighted-average amortization period of approximately five years. (7) Includes $40 million outstanding under letters of credit advances, which were repaid in January 2019, as well as $173 million outstanding commercial paper under various credit facilities. All such credit facilities were terminated in 2019. (8) Includes a $379 million pension and other postretirement benefit liability. (9) Includes stock-based compensation awards with a fair value of $21 million. Results of Operations and Unaudited Pro Forma Information The impact of the SCANA Combination on Dominion Energy’s operating revenue was an increase of $3.6 billion, $3.3 billion and $3.1 billion for the years ended December 31, 2021, 2020 and 2019, respectively, in the Consolidated Statements of Income. The impact of the SCANA Combination on Dominion Energy’s net income attributable to Dominion Energy was an increase of $287 million and $277 million for the years ended December 31, 2021 and 2020, respectively, and a decrease of $1.1 billion for the year ended December 31, 2019 in the Consolidated Statements of Income. Dominion Energy incurred merger and integration-related costs of $31 million and $97 million for the years ended December 31, 2021 and 2020, respectively, all of which is recorded in other operations and maintenance expense in the Consolidated Statements of Income. Dominion Energy incurred merger and integration-related costs of $646 million for the year ended December 31, 2019. The amount for the year ended December 31, 2019 includes $427 million for a charge related to a voluntary retirement program. See Note 22 for additional information. Of the remaining merger and integration-related costs, $210 million is recorded in other operations and maintenance expense and $9 million was recorded in interest and related charges in the Consolidated Statements of Income for the year ended December 31, 2019. These costs consist of professional fees, the charitable contribution commitment described above, employee-related expenses, certain financing costs and other miscellaneous costs. The following unaudited pro forma financial information reflects the consolidated results of operations of Dominion Energy assuming the SCANA Combination had taken place on January 1, 2018. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of the combined company. Twelve Months Ended December 31, 2019 (1) (millions, except EPS) Operating revenue $ 15,408 Net income attributable to Dominion Energy 3,266 Earnings Per Common Share – $ 4.04 Earnings Per Common Share – $ 4.00 (1) Amounts include adjustments for non-recurring costs directly related to the SCANA Combination. Sale of Interest in Cove Point In October 2019, Dominion Energy signed an agreement to sell its 25% noncontrolling limited partnership interests in Cove Point to Brookfield. In December 2019, the sale was completed and Dominion Energy received cash consideration of $2.1 billion, subject to working capital adjustments. The sale was accounted for by Dominion Energy following the guidance for a change in a parent company’s ownership interest in a consolidated subsidiary. Because Dominion Energy controlled Cove Point both before and after the sale of the noncontrolling interest, the change in Dominion Energy’s ownership interest in Cove Point was accounted for as an equity transaction and no gain or loss was recognized. Sale of Hope In February 2022, Dominion Energy entered into an agreement to sell 100% of the equity interests in Hope to Ullico for $690 million of cash consideration, subject to customary closing adjustments. The sale will be treated as a stock sale for tax purposes and is expected to close by the end of 2022, contingent on clearance or approval under the Hart-Scott-Rodino Act and from the West Virginia Commission, and other customary closing and regulatory conditions. While Dominion Energy is still completing its evaluation, it does not expect to record a significant gain or loss associated with the sale. Dominion Energy will reclassify the assets and liabilities to be disposed of, currently reflected in Gas Distribution, as held for sale starting in the first quarter of 2022. Sale of Kewaunee In May 2021, Dominion Energy entered into an agreement to sell 100% of the equity interests in Dominion Energy Kewaunee, Inc. to EnergySolutions, including the transfer of all decommissioning obligations associated with Kewaunee, which ceased operations in 2013. The agreement provides that Dominion Energy retains the assets and obligations of the pension and other postretirement employee benefit plans. In addition, Dominion Energy may continue to withdraw funds prior to closing from the nuclear decommissioning trust to recover certain spent nuclear fuel and other permitted costs, subject to certain conditions. The sale will be treated as an asset sale for tax purposes and is subject to termination by either party if not completed by December 2022. Closing is contingent on approval from the Wisconsin Commission as well as the NRC for the transfer of control of applicable licenses. The purchase agreement requires that EnergySolutions be subject to the Wisconsin regulatory conditions agreed to by Dominion Energy upon its acquisition of Kewaunee, including the return of any excess decommissioning funds to WPSC and WP&L customers following completion of all decommissioning activities. In May 2021, Dominion Energy and EnergySolutions submitted a license transfer application to the NRC. Also in May 2021, Dominion Energy submitted an application to the Wisconsin Commission for approval. In July 2021, WPSC and WP&L submitted a joint request to the Wisconsin Commission for the waiver of both of their rights of first refusal to purchase Kewaunee, such rights having been granted as the former owners of Kewaunee. At December 31, 2021, Dominion Energy determined that the assets and liabilities associated with the Kewaunee sale, included in Contracted Assets, did not meet the criteria to be classified as held for sale due to the significant uncertainty surrounding the timing of or ability to obtain necessary regulatory approvals. Dominion Energy expects to record a loss if and when it determines that criteria for the classification as held for sale have been met. If such classification had been made at December 31, 2021, Dominion Energy would have recognized a loss of approximately $725 million ($570 million after-tax). If the sale is ultimately completed, the final net loss will primarily depend on the value of the nuclear decommissioning trust and AROs at closing. Acquisition of Birdseye In May 2021, Dominion Energy acquired 100% of the ownership interest in Birdseye from BRE Holdings, LLC for total consideration of $46 million, consisting of $28 million in cash and $18 million, measured at fair value at closing, of consideration contingent on the achievement of certain revenue targets and future development project sales. Birdseye is primarily engaged in the development of solar energy projects in southeastern states in the U.S. with 2.5 GW of solar generation projects under development. The allocation of the purchase price resulted in $ 25 million of development project assets, primarily reflected in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets, and $ 24 million of goodwill, which is not deductible for tax purposes. The goodwill reflects the value associated with enhancing Dominion Energy's development of regulated and long-term contracted solar generating and electric storage projects. The fair value measurements, including of the assets acquired, were determined using the income approach and are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows. Birdseye is included in Contracted Assets .

Operating Revenue

Operating Revenue	12 Months Ended
	Dec. 31, 2021
Text Block [Abstract]
Operating Revenue	NOTE 4. OPERATING REVENUE The Companies’ operating revenue consists of the following: Year Ended December 31, 2021 2020 2019 (millions) Dominion Energy Regulated electric sales: Residential $ 4,509 $ 4,833 $ 4,325 Commercial 3,194 3,102 3,219 Industrial 748 730 683 Government and other retail 921 868 873 Wholesale 175 128 176 Nonregulated electric sales 1,005 823 941 Regulated gas sales: Residential 1,455 1,283 1,343 Commercial 527 457 457 Other 135 88 109 Nonregulated gas sales 96 174 495 Regulated gas transportation and storage 945 801 742 Other regulated revenues 265 327 252 Other nonregulated revenues (1)(2) 195 138 130 Total operating revenue from contracts with customers 14,170 13,752 13,745 Other revenues (3)(4) (206 ) 420 656 Total operating revenue $ 13,964 $ 14,172 $ 14,401 Virginia Power Regulated electric sales: Residential $ 3,366 $ 3,677 $ 3,657 Commercial 2,417 2,342 2,712 Industrial 367 380 455 Government and other retail 862 804 823 Wholesale 107 90 128 Nonregulated electric sales 44 19 15 Other regulated revenues 234 299 190 Other nonregulated revenues (1)(2) 73 50 56 Total operating revenue from contracts with customers 7,470 7,661 8,036 Other revenues (1)(3) — 102 72 Total operating revenue $ 7,470 $ 7,763 $ 8,108 (1) See Notes 9 and 25 for amounts attributable to related parties and affiliates. (2) Includes sales which are considered to be goods transferred at a point (3) Includes alternative revenue of $56 million, $119 million and $66 million at Dominion Energy and $44 million, $82 million and $52 million at Virginia Power for years ended December 31, 2021, 2020 and 2019, respectively. (4) Includes revenue associated with services provided to discontinued operations of $5 million, $4 million and $6 million for the years ended December 31, 2021, 2020 and 2019, respectively. 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 Dominion Energy expects to recognize this revenue. These revenues relate to contracts containing fixed prices where Dominion Energy will earn the associated revenue over time as it stands 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 Dominion Energy elects to recognize revenue in the amount it has a right to invoice. Revenue expected to be recognized on multi-year contracts in place at December 31, 2021 2022 2023 2024 2025 2026 Thereafter Total (millions) Dominion Energy (1) $ 68 $ 66 $ 59 $ 51 $ 45 $ 448 $ 737 (1) Includes no amounts for Virginia Power. Contract liabilities represent an entity’s obligation to transfer goods or services to a customer for which the entity has received consideration, or the amount that is due, from the customer. At December 31, 2021 and 2020, Dominion Energy’s contract liability balances were $124 million and $130 million, respectively. At December 31, 2021 and 2020, Virginia Power’s contract liability balances were $33 million and $36 million, respectively. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the Consolidated Balance Sheets. The Companies recognize revenue as they fulfill their obligations to provide service to their customers. During the years ended December 31, 2021 and 2020, Dominion Energy recognized revenue of $124 million and $97 million from the beginning contract liability balance. During the years ended December 31, 2021 and 2020, Virginia Power recognized revenue of $36 million and $24 million, respectively, from the beginning contract liability balance.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	NOTE 5. INCOME TAXES Judgment and the use of estimates are required in developing the provision for income taxes and reporting of tax-related assets and liabilities. The interpretation of tax laws and associated regulations involves uncertainty, since tax authorities may interpret the laws differently. The Companies are routinely audited by federal and state tax authorities. Ultimate resolution of income tax matters may result in favorable or unfavorable impacts to net income and cash flows, and adjustments to tax-related assets and liabilities could be material. The Companies have accounted for the effects of the 2017 Tax Reform Act, although additional changes could occur as guidance is issued and finalized as described below. In July 2020, the U.S. Department of Treasury issued final regulations providing guidance about the limitation on the deduction for business interest expenses under the 2017 Tax Reform Act. Under the 2017 Tax Reform Act, deductions for net interest expense are limited to 30% of adjusted taxable income, which has, until this point, been defined similarly to EBITDA (earnings before interest, taxes, depreciation and amortization). For tax years beginning after December 31, 2021, the calculation of adjusted taxable income is defined similarly to EBIT (earnings before interest and taxes). For consolidated groups such as Dominion Energy that have both regulated and nonregulated operations, these rules may result in a temporary disallowance of a portion of Dominion Energy’s interest deductions in the future, although any interest disallowed has an indefinite carryforward period. In December 2020, federal legislation was enacted that, among other things, provides a two-year extension of the beginning construction deadline for, and delays the phase-down of, the solar energy investment tax credit as well as extending the deadlines and phase-down rules for certain other renewable tax credits. The legislation provides that offshore wind facilities are eligible for the investment tax credit if construction on those facilities begins before 2026 with no phase-out. In addition, the U.S. Department of Treasury and the IRS issued guidance for offshore wind that extended the continuity of construction safe harbor to 10 years, which significantly enhances the ability for these projects to qualify for renewable energy tax credits. As indicated in Note 2, certain of the Companies’ operations, including accounting for income taxes, are subject to regulatory accounting treatment. For regulated operations, many of the changes in deferred taxes from the 2017 Tax Reform Act represent amounts probable of collection from or return to customers, and were recorded as either an increase to a regulatory asset or liability. See Note 13 for more information and current year developments. Continuing Operations Details of income tax expense for continuing operations including noncontrolling interests were as follows: Dominion Energy Virginia Power Year Ended December 2021 2020 2019 2021 2020 2019 (millions) Current: Federal $ (162 ) $ (314 ) $ (94 ) $ 67 $ 364 $ 286 State 45 (81 ) 58 (13 ) 71 58 Total current expense (benefit) (117 ) (395 ) (36 ) 54 435 344 Deferred: Federal Taxes before operating loss carryforwards, investment tax credits and tax reform 151 12 168 145 (226 ) (128 ) Tax utilization expense of operating loss carryforwards 43 44 119 — — — Investment tax credits 250 311 (51 ) (39 ) (27 ) (34 ) State (19 ) 72 (50 ) 118 7 22 Total deferred expense (benefit) 425 439 186 224 (246 ) (140 ) Investment tax credit-gross deferral 121 42 62 121 42 62 Investment tax credit-amortization (4 ) (3 ) (3 ) (2 ) (2 ) (2 ) Total income tax expense $ 425 $ 83 $ 209 $ 397 $ 229 $ 264 In 2021, Dominion Energy’s current income taxes reflect a benefit from continuing operations as the income tax expense associated with the QPipe Group’s operations, including taxes on the gain, is reflected in discontinued operations. Dominion Energy’s income tax expense reflects the utilization of investment tax credit carryforwards to offset a portion of the federal tax gain on the sale. In 2020, Dominion Energy’s current income taxes reflect a benefit from continuing operations as the income tax expense associated with gas transmission and storage operations, including taxes on the gain, is reflected in discontinued operations. Dominion Energy’s income tax expense reflects the utilization of investment tax credit carryforwards to offset a portion of the federal tax gain on the sale. In addition, an $18 million income tax benefit is reflected in common shareholders’ equity associated with state deferred taxes on assets and liabilities retained in connection with the GT&S Transaction. In 2019, the Dominion Energy Gas Restructuring caused changes in tax status at certain of its subsidiaries. The impacts of the changes in tax status decreased deferred income tax expense from continuing operations by $48 million at Dominion Energy. In addition, Dominion Energy recognized a taxable gain resulting from the sale of a 25% noncontrolling interest in Cove Point. The direct tax effects of the transactions included a provision for current income taxes ($362 million) and an offsetting benefit for deferred income taxes ($147 million) and were charged to common shareholders’ equity. The utilization of $208 million federal tax credit carryforwards offsetting a portion of the federal tax liability from the transaction were also charged to common shareholders’ equity. In total, the taxes recorded in common shareholders’ equity resulting from this transaction were $215 million. Discontinued Operations Income tax expense (benefit) reflected in discontinued operations is $188 million, $(204) million and $142 million for the years ended December 31, 2021, 2020 and 2019, respectively. 2021 income taxes include a $14 million benefit related to finalizing income tax returns on the GT&S Transaction and the absence of a $36 million benefit on non-deductible goodwill written off in connection with the sale of the Q-Pipe Group. The 2020 income tax expense reflects a charge of $81 million for the write-off of tax-related regulatory assets associated with the Atlantic Coast Pipeline Project and the absence of a $236 million benefit on non-deductible goodwill written off in connection with the GT&S Transaction. Continuing Operations 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 Year Ended December 2021 2020 2019 2021 2020 2019 U.S. statutory rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 2.6 2.0 1.5 4.6 4.8 4.5 Investment tax credits (3.2 ) (9.6 ) (11.4 ) (3.0 ) (4.5 ) (2.9 ) Production tax credits (0.4 ) (0.7 ) (2.1 ) (0.6 ) (0.7 ) (0.7 ) Valuation allowances 0.1 0.9 0.5 — — — Reversal of excess deferred income taxes (3.2 ) (5.4 ) (3.2 ) (2.1 ) (2.2 ) (3.1 ) State legislative change (0.7 ) — — (0.7 ) — — Write-off of regulatory assets — — 21.7 — — — Change in tax status — (1.7 ) (5.5 ) — — — AFUDC—equity (0.4 ) (0.2 ) (0.2 ) (0.5 ) — — Changes in state deferred taxes associated with assets held for sale (0.3 ) (3.2 ) — — — — Absence of tax on noncontrolling interest (0.1 ) 3.8 (0.2 ) — — — Settlements of uncertain tax positions (1.2 ) — — — — — Employee stock ownership plan deduction (0.3 ) (0.9 ) (1.4 ) — — — Nondeductible goodwill — — 1.8 — — — Other, net (0.2 ) (0.1 ) 1.5 0.1 (0.1 ) (0.2 ) Effective tax rate 13.7 % 5.9 % 24.0 % 18.8 % 18.3 % 18.6 % For the Companies’ rate-regulated entities, deferred taxes will reverse at the weighted average rate used to originate the deferred tax liability, which in some cases will be 35%. The Companies have recorded an estimate of excess deferred income tax amortization in 2021, and changes in estimates of amounts probable of collection from or return to customers. The reversal of these excess deferred income taxes will impact the effective tax rate, and rates charged to customers. See Note 13 for current year developments. In December 2021, unrecognized tax benefits related to several state uncertain tax positions acquired in the SCANA Combination were effectively settled through negotiations with the taxing authority. Management believed it was reasonably possible these unrecognized tax benefits could decrease through settlement negotiations or payments during 2021, however no income tax benefits could be recognized unless or until the positions were effectively settled. Resolution of these uncertain tax positions decreased income tax expense by $38 million. In addition, the Companies’ effective tax rates reflect the benefit of a state legislative change enacted in April 2021 for tax years beginning January 1, 2022. Dominion Energy’s effective tax rate reflects a $21 million deferred tax benefit, inclusive of a $16 million deferred tax benefit at Virginia Power. Dominion Energy’s 2020 effective tax rate reflects an income tax benefit of $45 million associated with the remeasurement of consolidated state deferred taxes with the classification of gas transmission and storage operations as held for sale. In addition, Dominion Energy’s effective tax rate reflects an income tax expense of $55 million attributable to the noncontrolling interest primarily associated with the impairment of non-wholly-owned nonregulated solar facilities held in partnerships discussed in Note 10. In connection with the SCANA Combination, Dominion Energy committed to forgo, or limit, the recovery of certain income tax-related regulatory assets associated with the NND Project. Dominion Energy’s effective tax rate reflects deferred income tax expense of $194 million in satisfaction of this commitment. Dominion Energy’s effective tax rate also reflects the changes in consolidated state income taxes resulting from the SCANA Combination. The Companies’ deferred income taxes consist of the following: Dominion Energy Virginia Power At December 2021 2020 2021 2020 (millions) Deferred income taxes: Total deferred income tax assets $ 3,025 $ 3,285 $ 1,373 $ 1,204 Total deferred income tax liabilities 9,397 9,069 4,286 3,832 Total net deferred income tax liabilities $ 6,372 $ 5,784 $ 2,913 $ 2,628 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 6,017 $ 5,824 $ 3,327 $ 3,227 Excess deferred income taxes (1,107 ) (1,142 ) (629 ) (656 ) Unrecovered NND Project costs 508 529 — — DESC rate refund (113 ) (140 ) — — Toshiba Settlement (189 ) (204 ) — — Nuclear decommissioning 1,114 991 324 303 Deferred state income taxes 857 702 420 305 Federal benefit of deferred state income taxes (179 ) (147 ) (88 ) (64 ) Deferred fuel, purchased energy and gas costs 189 (28 ) 126 (34 ) Pension benefits 362 239 (119 ) (105 ) Other postretirement benefits 73 (14 ) 93 76 Loss and credit carryforwards (1,571 ) (1,534 ) (537 ) (354 ) Valuation allowances 140 155 6 6 Partnership basis differences 398 593 — — Other (127 ) (40 ) (10 ) (76 ) Total net deferred income tax liabilities $ 6,372 $ 5,784 $ 2,913 $ 2,628 Deferred Investment Tax Credits – 286 169 270 151 Total Deferred Taxes and Deferred Investment Tax Credits $ 6,658 $ 5,953 $ 3,183 $ 2,779 At December 31, 2021, Dominion Energy had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration Amount Tax Asset Allowance Period (millions) Federal losses $ 965 $ 203 $ — 2037 Federal investment credits — 752 — 2036-2041 Federal production and other credits — 63 — 2036-2041 State losses 4,583 243 (50 ) 2022-2041 State minimum tax credits — 214 — No expiration State investment and other credits — 129 (90 ) 2022-2031 Total $ 5,548 $ 1,604 $ (140 ) At December 31, 2021, Virginia Power had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration Amount Tax Asset Allowance Period (millions) Federal losses $ — $ — $ — Federal investment credits — 467 — 2036-2041 Federal production and other credits — 62 — 2036-2041 State investment and other credits — 8 (6 ) 2024 Total $ — $ 537 $ (6 ) A reconciliation of changes in the Companies’ unrecognized tax benefits follows: Dominion Energy Virginia Power 2021 2020 2019 2021 2020 2019 (millions) Balance at January 1 $ 167 $ 175 $ 44 $ — $ — $ 2 Acquired unrecognized tax benefits — — 129 (1 ) — — — Increases-prior period positions 48 18 — — — — Decreases-prior period positions (59 ) (19 ) — — — — Increases-current period positions 2 1 9 — — — Settlements with tax authorities (26 ) — (7 ) — — (2 ) Expiration of statutes of limitations (4 ) (8 ) — — — — Balance at December 31 $ 128 $ 167 $ 175 $ - $ — $ - (1) Acquired unrecognized tax benefits reflect $106 million plus increases in prior period positions of $76 million and decreases in prior period positions of $53 million that were recorded through purchase accounting. Certain unrecognized tax benefits, or portions thereof, if recognized, would affect the effective tax rate. Changes in these unrecognized tax benefits may result from remeasurement of amounts expected to be realized, settlements with tax authorities and expiration of statutes of limitations. For Dominion Energy and its subsidiaries, these unrecognized tax benefits were $72 million, $140 million and $141 million at December 31, 2021, 2020 and 2019, respectively. In discontinued operations, these unrecognized tax benefits were $33 million at December 31, 2021. For Dominion Energy, the change in these unrecognized tax benefits decreased income tax expense by $34 million and $6 million in 2021 and 2020, respectively, and increased income tax expense by $3 million in 2019. For discontinued operations, the change in these unrecognized tax benefits increased income tax expense by $5 million in 2020 and decreased income tax expense by less than $1 million 2019. Dominion Energy participates in the IRS Compliance Assurance Process which provides the opportunity to resolve complex tax matters with the IRS before filing its federal income tax returns, thus achieving certainty for such tax return filing positions agreed to by the IRS. The IRS has completed its audit of tax years through 2019. The statute of limitations has not yet expired for years after 2017. Although Dominion Energy has not received a final letter indicating no changes to its taxable income for tax year 2020, no material adjustments are expected. The IRS examination of tax year 2021 is ongoing. It is reasonably possible that settlement negotiations and expiration of statutes of limitations could result in a decrease in unrecognized tax benefits in 2022 by up to $23 million for Dominion Energy. If such changes were to occur, other than revisions of the accrual for interest on tax underpayments and overpayments, earnings could increase by up to $9 million for Dominion Energy. Otherwise, with regard to 2021 and prior years, the Companies cannot estimate the range of reasonably possible changes to unrecognized tax benefits that may occur in 2022. For each of the major states in which Dominion Energy operates, the earliest tax year remaining open for examination is as follows: Earliest Open Tax State Year Pennsylvania (1) 2012 Connecticut 2018 Virginia (2) 2018 Utah 2018 South Carolina 2018 (1) Considered a major state for entities presented in discontinued operations. (2) Considered a major state for Virginia Power’s operations The Companies are also obligated to report adjustments resulting from IRS settlements to state tax authorities. In addition, if Dominion Energy utilizes operating losses or tax credits generated in years for which the statute of limitations has expired, such amounts are generally subject to examination.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	NOTE 6. FAIR VALUE MEASUREMENTS Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. However, the use of a mid-market pricing convention (the mid-point between bid and ask prices) is permitted. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of the Companies’ own nonperformance risk on their liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability (the market with the most volume and activity for the asset or liability from the perspective of the reporting entity), or in the absence of a principal market, the most advantageous market for the asset or liability (the market in which the reporting entity would be able to maximize the amount received or minimize the amount paid). Dominion Energy applies fair value measurements to certain assets and liabilities including commodity, interest rate and/or foreign currency exchange rate derivative instruments, and other investments including those held in nuclear decommissioning, rabbi, and pension and other postretirement benefit plan trusts, in accordance with the requirements discussed above. Virginia Power applies fair value measurements to certain assets and liabilities including commodity, interest rate and/or foreign currency exchange rate derivative instruments and other investments including those held in the nuclear decommissioning trust, in accordance with the requirements discussed above. The Companies apply credit adjustments to their derivative fair values in accordance with the requirements described above. Inputs and Assumptions Fair value is based on actively-quoted market prices, if available. In the absence of actively-quoted market prices, price information is sought from external sources, including industry publications, and to a lesser extent, broker quotes. When evaluating pricing information provided by Designated Contract Market settlement pricing, other pricing services, or brokers, the Companies consider the ability to transact at the quoted price, i.e. if the quotes are based on an active market or an inactive market and to the extent which pricing models are used, if pricing is not readily available. If pricing information from external sources is not available, or if the Companies believe that observable pricing is not indicative of fair value, judgment is required to develop the estimates of fair value. In those cases the unobservable inputs are developed and substantiated using historical information, available market data, third-party data and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships and changes in third-party sources. For options and contracts with option-like characteristics where observable pricing information is not available from external sources, the Companies generally use a modified Black-Scholes Model that considers time value, the volatility of the underlying commodities and other relevant assumptions when estimating fair value. The Companies use other option models under special circumstances, including but not limited to Spread Approximation Model and a Swing Option Model. For contracts with unique characteristics, the Companies may estimate fair value using a discounted cash flow approach deemed appropriate in the circumstances and applied consistently from period to period. For individual contracts, the use of different valuation models or assumptions could have a significant effect on the contract’s estimated fair value. The inputs and assumptions used in measuring fair value include the following: For commodity derivative contracts: • Forward commodity prices • Transaction prices • Price volatility • Price correlation • Volumes • Commodity location • Interest rates • Credit quality of counterparties and the Companies • Credit enhancements • Time value For interest rate derivative contracts: • Interest rate curves • Credit quality of counterparties and the Companies • Notional value • Credit enhancements • Time value For foreign currency exchange rate derivative contracts: • Foreign currency forward exchange rates • Interest rates • Credit quality of counterparties and the Companies • Notional value • Time value For investments: • Quoted securities prices and indices • Securities trading information including volume and restrictions • Maturity • Interest rates • Credit quality of counterparties and the Companies Levels The Companies also utilize the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: • Level 1—Quoted prices (unadjusted) in active markets for identical assets and liabilities that they have the ability to access at the measurement date. Instruments categorized in Level 1 primarily consist of financial instruments such as certain exchange-traded derivatives, and exchange-listed equities, U.S. and international equity securities, mutual funds and certain Treasury securities held in nuclear decommissioning trust funds for the Companies and benefit plan trust funds and rabbi trust funds for Dominion Energy. • Level 2—Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 primarily include commodity forwards and swaps, interest rate swaps, foreign currency exchange rate instruments and cash and cash equivalents, corporate debt instruments, government securities and other fixed income investments held in nuclear decommissioning trust funds for the Companies and benefit plan trust funds and rabbi trust funds for Dominion Energy. • Level 3—Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity for the asset or liability. Instruments categorized in Level 3 for the Companies consist of long-dated commodity derivatives, FTRs, certain natural gas options and other modeled commodity derivatives. The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability. Alternative investments, consisting of investments in partnerships, joint ventures and other alternative investments held in nuclear decommissioning and benefit plan trust funds, are generally valued using NAV based on the proportionate share of the fair value as determined by reference to the most recent audited fair value financial statements or fair value statements provided by the investment manager adjusted for any significant events occurring between the investment manager’s and the Companies’ measurement date. Alternative investments recorded at NAV are not classified in the fair value hierarchy. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable for classification in either Level 1 or Level 2. Because the activity and liquidity of commodity markets vary substantially between regions and time periods, the availability of observable inputs for substantially the full term and value of the Companies’ over-the-counter derivative contracts is subject to change. Level 3 Valuations The Companies enter into certain physical and financial forwards, futures, options and swaps, which are considered Level 3 as they have one or more inputs that are not observable and are significant to the valuation. The discounted cash flow method is used to value Level 3 physical and financial forwards and futures contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices and volumes. For Level 3 fair value measurements, certain forward market prices and implied price volatilities are considered unobservable. The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at December 31, 2021. 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: Natural gas (2) $ 54 Discounted cash flow Market price (per Dth) (3) (2)-8 (1 ) FTRs 51 Discounted cash flow Market price (per MWh) (3) (2)-11 2 Electricity 120 Discounted cash flow Market price (per MWh) (3) 28-72 43 Physical options: Natural gas 5 Option model Market price (per Dth) (3) 3-9 6 Price volatility (4) 19% - 27% 24 % Total assets $ 230 Liabilities Physical and financial forwards: Natural gas (2) $ 3 Discounted cash flow Market price (per Dth) (3) (2)-4 (1 ) FTRs 5 Discounted cash flow Market price (per MWh) (3) (3)-7 1 Total liabilities $ 8 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents 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) Nonrecurring Fair Value Measurements Dominion Energy See Note 3 for information on the nonrecurring fair value measurement associated with the acquisition of Birdseye. See Note 9 for information regarding nonrecurring fair value measurements associated with Dominion Energy’s retained noncontrolling interest in Cove Point, charges related to Fowler Ridge and Dominion Energy’s retained noncontrolling interest in businesses and assets contributed to Wrangler. See Note 10 for information regarding an impairment charge recorded associated with non-wholly-owned nonregulated solar facilities in partnerships. In 2021, Dominion Energy recorded a charge of $20 million ($15 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income (reflected in the Corporate and Other segment) to write off substantially all of the long-lived assets of its nonregulated retail software development operations to their estimated fair value, using a market approach, of less than $1 million. The valuation is considered a Level 2 fair value measurement given that it is based on bids received. In 2021, Dominion Energy recorded a charge of $16 million ($12 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income to adjust a corporate office building down to its estimated fair value, using both an income and market approach, of $26 million. The valuation is considered a Level 3 measurement due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates inherent in the future cash flows and market prices. The corporate office building is reflected in the Corporate and Other segment and presented as held for sale in Dominion Energy’s Consolidated Balance Sheets at December 31, 2021. Recurring Fair Value Measurements Fair value measurements are separately disclosed by level within the fair value hierarchy with a separate reconciliation of fair value measurements categorized as Level 3. Fair value disclosures for assets held in Dominion Energy’s pension and other postretirement benefit plans are presented in Note 22. 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) December 31, 2021 Assets Derivatives: Commodity $ — $ 52 $ 230 $ 282 Interest rate — 323 — 323 Foreign currency exchange rate — 8 — 8 Investments (1) Equity securities: U.S. 5,241 — — 5,241 Fixed income: Corporate debt instruments — 881 — 881 Government securities 199 1,256 — 1,455 Cash equivalents and other (29 ) — — (29 ) Total assets $ 5,411 $ 2,520 $ 230 $ 8,161 Liabilities Derivatives: Commodity $ — $ 461 $ 8 $ 469 Interest rate — 399 — 399 Total liabilities $ — $ 860 $ 8 $ 868 December 31, 2020 Assets Derivatives: Commodity $ — $ 57 $ 110 $ 167 Interest rate — 230 — 230 Investments (1) Equity securities: U.S. 4,648 — — 4,648 Fixed income: Corporate debt instruments — 629 — 629 Government securities 508 730 — 1,238 Cash equivalents and other 32 15 — 47 Total assets $ 5,188 $ 1,661 $ 110 $ 6,959 Liabilities Derivatives: Commodity $ — $ 48 $ 7 $ 55 Interest rate — 431 — 431 Total liabilities $ — $ 479 $ 7 $ 486 (1) Includes investments held in the nuclear decommissioning trusts and rabbi trusts. Excludes $366 million and $340 million of assets at December 31, 2021 and 2020, 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: 2021 2020 2019 (millions) Balance at January 1, $ 103 $ (37 ) $ 64 Total realized and unrealized gains (losses): Included in earnings: Operating Revenue (9 ) — (1 ) Electric fuel and other energy-related purchases 10 (33 ) (22 ) Purchased gas — — 2 Discontinued operations — 1 — Included in regulatory assets/liabilities 119 140 (90 ) Settlements (10 ) 33 17 Purchases — — (10 ) Sales — (1 ) 6 Transfers out of Level 3 9 — (3 ) Balance at December 31, $ 222 $ 103 $ (37 ) There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the years ended December 31, 2021, 2020 and 2019. Virginia Power The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at December 31, 2021. 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: Natural gas (2) $ 54 Discounted cash flow Market price (per Dth) (3) (2)-6 (1 ) FTRs 51 Discounted cash flow Market price (per MWh) (3) (2)-11 2 Physical options: Natural gas 5 Option model Market price (per Dth) (3) 3-9 6 Price volatility (4) 19% - 27% 24 % Total assets $ 110 Liabilities Physical and financial forwards: Natural gas (2) $ 3 Discounted cash flow Market price (per Dth) (3) (2)-4 (1 ) FTRs 5 Discounted cash flow Market price (per MWh) (3) (3)-7 1 Total liabilities $ 8 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents 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) December 31, 2021 Assets Derivatives: Commodity $ — $ 36 $ 110 $ 146 Interest rate — 146 — 146 Foreign currency exchange rate — 8 — 8 Investments (1) Equity securities: U.S. 2,420 — — 2,420 Fixed income: Corporate debt instruments — 531 — 531 Government securities 93 506 — 599 Cash equivalents and other (3 ) — — (3 ) Total assets $ 2,510 $ 1,227 $ 110 $ 3,847 Liabilities Derivatives: Commodity $ — $ 125 $ 8 $ 133 Interest rate — 337 — 337 Total liabilities $ — $ 462 $ 8 $ 470 December 31, 2020 Assets Derivatives: Commodity $ — $ 5 $ 110 $ 115 Interest rate — 66 — 66 Investments (1) Equity securities: U.S. 2,171 — — 2,171 Fixed income: Corporate debt instruments — 348 — 348 Government securities 201 309 — 510 Cash equivalents and other 13 — — 13 Total assets $ 2,385 $ 728 $ 110 $ 3,223 Liabilities Derivatives: Commodity $ — $ 22 $ 7 $ 29 Interest rate — 376 — 376 Total liabilities $ — $ 398 $ 7 $ 405 (1) Includes investments held in the nuclear decommissioning trusts. Excludes $185 million and $167 million of assets at December 31, 2021 and 2020, 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: 2021 2020 2019 (millions) Balance at January 1, $ 103 $ (37 ) $ 60 Total realized and unrealized gains (losses): Included in earnings: Electric fuel and other energy-related purchases 4 (33 ) (22 ) Included in regulatory assets/liabilities (1 ) 140 (88 ) Settlements (4 ) 33 13 Balance at December 31, $ 102 $ 103 $ (37 ) There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the years ended December 31, 2021, 2020 and 2019. Fair Value of Financial Instruments Substantially all of the Companies’ financial instruments are recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of cash, restricted cash and equivalents, customer and other receivables, affiliated receivables, short-term debt, affiliated current borrowings, payables to affiliates and accounts payable are representative of fair value because of the short-term nature of these instruments. For the Companies’ financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows: December 31, 2021 2020 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Energy Long-term debt (2)(3) $ 35,996 $ 40,947 $ 31,996 $ 38,773 Supplemental 364-Day credit facility borrowings — — 225 225 Junior subordinated notes (4) 1,386 1,470 3,411 3,633 Virginia Power Long-term debt (4) $ 13,753 $ 16,021 $ 13,207 $ 16,455 (1) Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value. (2) Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs and discount or premium. At December 31, 2021 and December 31, 2020, the carrying amount includes the valuation of certain fair value hedges associated with fixed rate debt of $2 million and $3 million, respectively. (3) Includes amounts classified as held for sale at December 31, 2020, see Note 3. ( 4 ) Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs, discount or premium.

Derivatives and Hedge Accountin

Derivatives and Hedge Accounting Activities	12 Months Ended
	Dec. 31, 2021
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivatives and Hedge Accounting Activities	NOTE 7. DERIVATIVES AND HEDGE ACCOUNTING ACTIVITIES See Note 2 for the Companies’ accounting policies, objectives, and strategies for using derivative instruments. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. Derivative assets and liabilities are presented gross on the Companies’ Consolidated Balance Sheets. Dominion Energy and Virginia Power’s derivative contracts include both over-the-counter transactions and those that are executed on an exchange or other trading platform (exchange contracts) and centrally cleared. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange or clearinghouse to enter, execute or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency or other conditions. In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases, other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities. In February 2022, Dominion Energy entered into contracts representing offsetting positions to certain existing exchange contracts with collateral requirements as well as new over-the-counter transactions that are not subject to collateral requirements. These contracts resulted in positions which limit the risk of increased cash collateral requirements. Certain accounts receivable and accounts payable recognized on the Companies’ Consolidated Balance Sheets, letters of credit and other forms of securities, as well as certain other long-term debt , 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 18 for further information regarding other long-term debt, in the form of restructured derivatives, subject to offset under master netting or similar agreements. See Note 24 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, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 153 $ 13 $ — $ 140 $ 117 $ 9 $ — $ 108 Exchange 9 7 — 2 49 24 — 25 Interest rate contracts: Over-the-counter 323 49 — 274 230 13 — 217 Foreign currency exchange rate contracts: Over-the-counter 8 — — 8 — — — — Total derivatives, subject to a master netting or similar arrangement $ 493 $ 69 $ — $ 424 $ 396 $ 46 $ — $ 350 (1) Excludes $120 million and $1 million of derivative assets at December 31, 2021 and 2020, respectively, December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 95 $ 13 $ 54 $ 28 $ 30 $ 9 $ — $ 21 Exchange 374 7 367 — 24 24 — — Interest rate contracts: Over-the-counter 399 49 11 339 431 13 17 401 Total derivatives, subject to a master netting or similar arrangement $ 868 $ 69 $ 432 $ 367 $ 485 $ 46 $ 17 $ 422 (1) Excludes $1 million of derivative liabilities at December 31, 2020 Volumes The following table presents the volume of Dominion Energy’s derivative activity as of December 31, 2021. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 34 5 Basis 156 446 Electricity (MWh in millions): Fixed price 15 31 FTRs 44 — Interest rate (2) $ 1,537 $ 9,859 Foreign currency exchange rate (2) 501 kr. 4,581 kr. (1) Includes options. (2) Maturity is determined based on final settlement period. AOCI The following table presents selected information related to losses on cash flow hedges included in AOCI in Dominion Energy’s Consolidated Balance Sheets at December 31, 2021: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (358 ) $ (40 ) 396 months Total $ (358 ) $ (40 ) The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest rate 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 interest rates. Fair Value Hedges For derivative instruments that are designated and qualify as a fair value hedge, the gain or loss on the derivative instrument as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in current earnings and presented in the same line item. There were no derivative instruments designated as fair value hedges during the twelve months ended December 31, 2021 and 2020. Gains and losses on derivative fair value hedge relationships were immaterial for the year ended December 31, 2019. The following table presents the amounts recorded on the Consolidated Balance Sheets related to cumulative basis adjustments for fair value hedges all of which related to discontinued hedging relationships at both December 31, 2021 and 2020, respectively: Carrying Amount of the Hedged Asset (Liability) Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets (Liabilities) December 31, 2021 December 31, 2020 December 31, 2021 December 31, 2020 (millions) Long-term debt $ (352 ) $ (1,153 ) $ (2 ) $ (3 ) Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2021 ASSETS Current Assets Commodity $ — $ 103 $ 103 Interest rate 1 17 18 Foreign currency exchange rate — 1 1 Total current derivative assets (1) 1 121 122 Noncurrent Assets Commodity — 179 179 Interest rate 145 160 305 Foreign currency exchange rate — 7 7 Total noncurrent derivative assets (2) 145 346 491 Total derivative assets $ 146 $ 467 $ 613 LIABILITIES Current Liabilities Commodity $ — $ 304 $ 304 Interest rate 42 13 55 Total current derivative liabilities (3) 42 317 359 Noncurrent Liabilities Commodity — 165 165 Interest rate 295 49 344 Total noncurrent derivative liabilities (4) 295 214 509 Total derivative liabilities $ 337 $ 531 $ 868 At December 31, 2020 ASSETS Current Assets Commodity $ — $ 58 $ 58 Interest rate — 9 9 Total current derivative assets (1) — 67 67 Noncurrent Assets Commodity — 109 109 Interest rate 66 155 221 Total noncurrent derivative assets (2) 66 264 330 Total derivative assets $ 66 $ 331 $ 397 LIABILITIES Current Liabilities Commodity $ — $ 42 $ 42 Interest rate 363 10 373 Total current derivative liabilities (3) 363 52 415 Noncurrent Liabilities Commodity — 13 13 Interest rate 19 39 58 Total noncurrent derivative liabilities (4) 19 52 71 Total derivative liabilities $ 382 $ 104 $ 486 (1) At December 31, 2021, all current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $63 million is included in other current assets and the remainder is recorded in current assets held for sale. (2) A t December 31, 2021, all noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets . At December 31, 2020, $ 330 million is included in other deferred charges and other assets and the remainder is recorded in noncurrent assets held for sale. (3) At December 31, 2021, all current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $412 million is included in other current liabilities and the remainder is recorded in current liabilities held for sale. (4) At December 31, 2021, all noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $71 million is included in other deferred credits and other liabilities and the remainder is recorded in noncurrent liabilities held for sale. 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 (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2021 Derivative type and location of gains (losses): Commodity (3) $ (1 ) Interest rate (4) $ 21 (60 ) $ 135 Total $ 21 $ (61 ) $ 135 Year Ended December 31, 2020 Derivative type and location of gains (losses): Commodity: Operating revenue $ 25 Purchased gas (4 ) Discontinued operations 2 Total commodity $ — $ 23 $ — Interest rate: Interest and related charges $ (83 ) Discontinued operations (236 ) Total interest rate $ (309 ) $ (319 ) $ (332 ) Foreign currency exchange rate (5) (11 ) (6 ) — Total $ (320 ) $ (302 ) $ (332 ) Year Ended December 31, 2019 Derivative type and location of gains (losses): Commodity: Operating revenue $ 142 Purchased gas (3 ) Discontinued operations 4 Total commodity $ 125 $ 143 $ — Interest rate: Interest and related charges $ (49 ) Discontinued operations (5 ) Total interest rate $ (252 ) $ (54 ) $ (255 ) Foreign currency exchange rate (5) (18 ) (6 ) — Total $ (145 ) $ 83 $ (255 ) (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 purchased gas. (4) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges. ( 5 ) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in discontinued operations. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in Income on Derivatives (1) Year Ended December 31, 2021 2020 2019 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (487 ) $ 73 $ 41 Purchased gas (1 ) (20 ) (22 ) Electric fuel and other energy-related purchases 16 (104 ) (46 ) Discontinued operations — (11 ) (2 ) Interest rate: Interest and related charges 97 87 3 Discontinued operations — 5 — Foreign currency exchange rate: Discontinued operations — 12 — Total $ (375 ) $ 42 $ (26 ) (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, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 110 $ 8 $ — $ 102 $ 111 $ 6 $ — $ 105 Exchange 7 7 — — 1 1 — — Interest rate contracts: Over-the-counter 146 20 — 126 66 7 — 59 Foreign currency exchange rate contracts: Over-the-counter 8 — — 8 — — — — Total derivatives, subject to a master netting or similar arrangement $ 271 $ 35 $ — $ 236 $ 178 $ 14 $ — $ 164 (1) Excludes $29 million and $3 million of derivative assets at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements. December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 84 $ 8 $ 54 $ 22 $ 6 $ 6 $ — $ — Exchange 43 7 36 — 1 1 — — Interest rate contracts: Over-the-counter 337 20 — 317 376 7 — 369 Total derivatives, subject to a master netting or similar arrangement $ 464 $ 35 $ 90 $ 339 $ 383 $ 14 $ — $ 369 (1) Excludes $6 million and $22 million of derivative liabilities at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements. Volumes The following table presents the volume of Virginia Power’s derivative activity at December 31, 2021. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 24 5 Basis 139 440 Electricity (MWh in millions): Fixed price 6 7 FTRs 44 — Interest rate (2) $ 1,000 $ 1,750 Foreign currency exchange rate (2) 501 kr. 4,581 kr. (1) Includes options. (2) Maturity is determined based on final settlement period. AOCI The following table presents selected information related to losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheets at December 31, 2021: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (45 ) $ (2 ) 396 months Total $ (45 ) $ (2 ) The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest payments) in earnings, thereby achieving the realization of interest rates contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in interest rates. Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2021 ASSETS Current Assets Commodity $ — $ 74 $ 74 Interest rate 1 — 1 Foreign currency exchange rate — 1 1 Total current derivative assets (1) 1 75 76 Noncurrent Assets Commodity — 72 72 Interest rate 145 — 145 Foreign currency exchange rate — 7 7 Total noncurrent derivative assets (2) 145 79 224 Total derivative assets $ 146 $ 154 $ 300 LIABILITIES Current Liabilities Commodity $ — $ 92 $ 92 Interest rate 42 — 42 Total current derivative liabilities 42 92 134 Noncurrent Liabilities Commodity — 41 41 Interest rate 295 — 295 Total noncurrent derivatives liabilities (3) 295 41 336 Total derivative liabilities $ 337 $ 133 $ 470 At December 31, 2020 ASSETS Current Assets Commodity $ — $ 22 $ 22 Total current derivative assets (1) — 22 22 Noncurrent Assets Commodity — 93 93 Interest rate 66 — 66 Total noncurrent derivative assets (2) 66 93 159 Total derivative assets $ 66 $ 115 $ 181 LIABILITIES Current Liabilities Commodity $ — $ 28 $ 28 Interest rate 362 — 362 Total current derivative liabilities 362 28 390 Noncurrent Liabilities Commodity — 1 1 Interest rate 14 — 14 Total noncurrent derivatives liabilities (3) 14 1 15 Total derivative liabilities $ 376 $ 29 $ 405 (1) Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets. (3) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets. The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income: Derivatives in cash flow hedging relationships Amount of Gain (Loss) Recognized in AOCI on Derivatives (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2021 Derivative type and location of gains (losses): Interest rate (3) $ 17 $ (3 ) $ 130 Total $ 17 $ (3 ) $ 130 Year Ended December 31, 2020 Derivative type and location of gains (losses): Interest rate (3) $ (37 ) $ (2 ) $ (338 ) Total $ (37 ) $ (2 ) $ (338 ) Year Ended December 31, 2019 Derivative type and location of gains (losses): Interest rate (3) $ (30 ) $ (1 ) $ (259 ) Total $ (30 ) $ (1 ) $ (259 ) (1) Amounts deferred into AOCI have no associated effect in Virginia Power’s Consolidated Statements of Income. (2) Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power’s Consolidated Statements of Income. (3) Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges. Derivatives not designated as hedging instruments Amount of Gain (Loss) Recognized in Income on Derivatives (1) Year Ended December 31, 2021 2020 2019 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (62 ) $ (104 ) $ (45 ) Electric fuel and other energy-related purchases 9 — — Total $ (53 ) $ (104 ) $ (45 ) (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.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Earnings Per Share	NOTE 8. EARNINGS PER SHARE The following table presents the calculation of Dominion Energy’s basic and diluted EPS: 2021 2020 2019 (millions, except EPS) Net income attributable to Dominion Energy from continuing operations $ 2,647 $ 1,583 $ 653 Preferred stock dividends (see Note 19) (68 ) (65 ) (17 ) Net income attributable to Dominion Energy from continuing operations - Basic 2,579 1,518 636 Dilutive effect of Series A Preferred Stock — (11 ) (28 ) Net income attributable to Dominion Energy from continuing operations - Diluted 2,579 $ 1,507 $ 608 Net income (loss) attributable to Dominion Energy from discontinued operations - Basic & Diluted 641 $ (1,984 ) $ 705 Average shares of common stock outstanding – Basic 807.8 831.0 808.8 Net effect of dilutive securities (1) 0.7 — 0.1 Average shares of common stock outstanding – Diluted 808.5 831.0 808.9 EPS from continuing operations - Basic $ 3.19 $ 1.83 $ 0.79 EPS from discontinued operations - Basic 0.79 (2.39 ) 0.87 EPS attributable to Dominion Energy - Basic $ 3.98 $ (0.56 ) $ 1.66 EPS from continuing operations - Diluted 3.19 $ 1.82 $ 0.75 EPS from discontinued operations - Diluted 0.79 (2.39 ) 0.87 EPS attributable to Dominion Energy - Diluted $ 3.98 $ (0.57 ) $ 1.62 (1) Dilutive securities for 2021 consist primarily of stock expected to be issued to satisfy the obligation under a settlement agreement with the SCDOR (applying the if converted method) as well as forward sales agreements entered into in November 2021 (applying the treasury stock method). See Notes 20 and 23 for additional information. The 2019 Equity Units, the Q-Pipe Transaction deposit, prior to being settled in cash in July 2021 and the 2016 Equity Units, prior to being settled via stock issuances in August 2019, are potentially dilutive instruments. See Notes 3, 18 and 19 for additional information. The forward stock purchase contracts included within the 2019 Equity Units were excluded from the calculation of diluted EPS from continuing operations for the years ended December 31, 2021, 2020 and 2019 as the dilutive stock price threshold was not met. The Series A Preferred Stock included within the 2019 Equity Units is excluded from the effect of dilutive securities within diluted EPS from continuing operations, but a fair value adjustment is reflected within net income attributable to Dominion Energy from continuing operations for the calculation of diluted EPS from continuing operations for the years ended December 31, 2020 and 2019, based upon the expectation that the conversion will be settled in cash rather than through the issuance of Dominion Energy common stock. As described in Note 19, effective November 2021 any settlement of the conversion up to $1,000 per share is payable in cash, and any amount in excess of $1,000 per share may be settled in cash, common stock or a combination thereof. For the year ended December 31, 2021, a fair value adjustment related to the Series A Preferred Stock included within the 2019 Equity Units is excluded from the calculation of diluted EPS from continuing operations, as such fair value adjustment was not dilutive during the period. The impact of settling the deposit associated with the Q-Pipe Transaction in shares is excluded from the calculation for the years ending December 31, 2021 and 2020 based upon the expectation Dominion Energy would settle in cash, which occurred in July 2021, rather than through the issuance of shares of Dominion Energy common stock. The 2016 Equity Units were potentially dilutive securities but were excluded from the calculation of diluted EPS from continuing operations for year ended December 31, 2019 as the dilutive stock price threshold was not met.

Investments

Investments	12 Months Ended
	Dec. 31, 2021
Investments Debt And Equity Securities [Abstract]
Investments	NOTE 9. INVESTMENTS Dominion Energy Equity and Debt Securities Rabbi Trust Securities Equity and fixed income securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled $122 million and $134 million at December 31, 2021 and 2020, respectively. Decommissioning Trust Securities Dominion Energy holds equity and fixed income securities, insurance contracts and cash equivalents 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 Allowance for Credit Losses Fair Value (millions) December 31, 2021 Equity securities: (1) U.S. $ 1,567 $ 3,734 $ (13 ) $ 5,288 Fixed income securities: (2) Corporate debt instruments 854 32 (5 ) $ — 881 Government securities 1,382 43 (7 ) — 1,418 Common/collective trust funds 168 4 — — 172 Insurance contracts 255 — — 255 Cash equivalents and other (3) 9 2 (75 ) — (64 ) Total $ 4,235 $ 3,815 $ (100 ) (4) $ — $ 7,950 December 31, 2020 Equity securities: (1) U.S. $ 1,756 $ 2,948 $ (24 ) $ 4,680 Fixed income securities: (2) Corporate debt instruments 572 58 (1 ) $ — 629 Government securities 1,119 66 (1 ) — 1,184 Common/collective trust funds 170 5 — — 175 Insurance contracts 237 — — 237 Cash equivalents and other (3) (8 ) 4 (1 ) — (5 ) Total $ 3,846 $ 3,081 $ (27 ) (4) $ — $ 6,900 (1) Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. Changes in allowance for credit losses are included in other income. (3) Includes pending purchases of securities of $35 million and $49 million at December 31, 2021 and 2020, respectively. (4) The fair value of securities in an unrealized loss position was $883 million and $293 million at December 31, 2021 and 2020, respectively. The portion of unrealized gains and losses that relates to equity securities held within Dominion Energy’s nuclear decommissioning trusts is summarized below: Year Ended December 31, 2021 2020 2019 (millions) Net gains (losses) recognized during the period $ 1,072 $ 512 $ 919 Less: Net gains recognized during the period on securities sold during the period (346 ) (16 ) (80 ) Unrealized gains (losses) recognized during the period on securities still held at period end (1) $ 726 $ 496 $ 839 (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. The fair value of Dominion Energy’s fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2021 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 331 Due after one year through five years 642 Due after five years through ten years 630 Due after ten years 868 Total $ 2,471 Presented below is selected information regarding Dominion Energy’s equity and fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2021 2020 2019 (millions) Proceeds from sales $ 3,985 $ 4,278 $ 1,712 Realized gains (1) 441 340 195 Realized losses (1) 91 297 96 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2. Virginia Power Virginia Power holds equity and fixed income securities and cash equivalents 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 Allowance for Credit Losses Fair Value (millions) December 31, 2021 Equity securities: (1) U.S. $ 841 $ 1,720 $ (11 ) $ 2,550 Fixed income securities: (2) Corporate debt instruments 517 17 (3 ) $ — 531 Government securities 584 16 (2 ) — 598 Common/collective trust funds 53 — — — 53 Cash equivalents and other (3) 2 — — — 2 Total $ 1,997 $ 1,753 $ (16 ) (4) $ — $ 3,734 December 31, 2020 Equity securities: (1) U.S. $ 929 $ 1,371 $ (21 ) $ 2,279 Fixed income securities: (2) Corporate debt instruments 315 33 — $ — 348 Government securities 484 25 — — 509 Common/collective trust funds 58 — — — 58 Cash equivalents and other (3) 3 — — — 3 Total $ 1,789 $ 1,429 $ (21 ) (4) $ — $ 3,197 (1) Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2 (2) Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. Changes in allowance for credit losses are included in other income. (3) Includes pending sales of securities of $5 million at December 31, 2021, and pending purchases of securities of $10 million at December 31, 2020. (4) The fair value of securities in an unrealized loss position was $425 million and $142 million at December 31, 2021 and 2020, respectively. The portion of unrealized gains and losses that relates to equity securities held within Virginia Power’s nuclear decommissioning trusts is summarized below: Year Ended December 31, 2021 2020 2019 (millions) Net gains (losses) recognized during the period $ 552 $ 224 $ 423 Less: Net gains recognized during the period on securities sold during the period (190 ) (6 ) (20 ) Unrealized gains (losses) recognized during the period on securities still held at end of period (1) $ 362 $ 218 $ 403 (1) Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. The fair value of Virginia Power’s fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2021, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 78 Due after one year through five years 335 Due after five years through ten years 361 Due after ten years 408 Total $ 1,182 Presented below is selected information regarding Virginia Power’s equity and fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2021 2020 2019 (millions) Proceeds from sales $ 1,791 $ 884 $ 858 Realized gains (1) 228 88 58 Realized losses (1) 35 68 22 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2. EQUITY METHOD INVESTMENTS Investments that Dominion Energy accounts for under the equity method of accounting are as follows: Investment Company Ownership% Balance Description As of December 2021 2020 (millions) Cove Point 50 % $ 2,738 $ 2,784 LNG import/export and storage facility Atlantic Coast Pipeline 53 % — (3) — (3) Gas transmission system Wrangler 15 % (2) 68 74 Nonregulated retail energy marketing Align RNG (1) 50 % 74 25 Renewable natural gas Other various 52 51 Total $ 2,932 $ 2,934 (1) Dominion Energy’s unfunded commitment to be made to Align RNG by the end of 2022 was $8 million and $59 million at December 31, 2021 and 2020, respectively. The commitment was fully paid in January 2022. (2) Dominion Energy’s ownership interest became 15% in December 2021, following the sale of 5% of its ownership interest. See discussion below. (3) Dominion Energy’s Consolidated Balance Sheets include a liability associated with its investment in Atlantic Coast Pipeline of $113 million and $1.1 billion at December 31, 2021 and 2020, respectively. See discussion below for additional information. Dominion Energy recorded equity earnings on its investments of $276 million, $40 million and $8 million in 2021, 2020 and 2019, respectively, in its Consolidated Statements of Income. In addition, Dominion Energy recorded equity earnings (losses) of $(20) million, $(2.3) billion and $117 million in 2021, 2020 and 2019, respectively, in discontinued operations related to its investment in Atlantic Coast Pipeline. Dominion Energy received distributions from these investments of $328 million, $102 million and $38 million in 2021, 2020 and 2019, respectively. As of December 31, 2021 and 2020, the net difference between the carrying amount of Dominion Energy’s investments and its share of underlying equity in net assets was $244 million and $213 million, respectively. At December 31, 2021, these differences are comprised of $27 million of equity method goodwill that is not being amortized, $221 million basis difference from Dominion Energy’s investment in Cove Point, which is being amortized over the useful lives of the underlying assets and a net $(4) million basis difference primarily attributable to an unfunded commitment made to Align RNG. At December 31, 2020, these differences are comprised of $27 million of equity method goodwill that is not being amortized, $227 million basis difference from Dominion Energy’s investment in Cove Point, which is being amortized over the useful lives of the underlying assets and a net $(41) million basis difference primarily attributable to an unfunded commitment made to Align RNG. Cove Point Prior to January 2019, Dominion Energy owned all of the common equity interest in Cove Point except for a preferred equity interest held by Dominion Energy Midstream (entitled to the first $50 million of annual cash distributions by Cove Point), in which Dominion Energy owned a controlling financial interest and consolidated. As discussed in Note 20, Dominion Energy acquired all of the outstanding partnership interests of Dominion Energy Midstream not owned by Dominion Energy in January 2019. In December 2019, Dominion Energy closed on an agreement to sell a 25% noncontrolling limited partnership interest in Cove Point. In November 2020, in conjunction with the GT&S Transaction, Dominion Energy sold 100% of its general partner interest and 25% of the total limited partner interest in Cove Point. Dominion Energy retained a 50% noncontrolling limited partnership interest in Cove Point which is accounted for as an equity method investment as Dominion Energy has the ability to exercise significant influence over, but not control, Cove Point. See Note 3 for further information regarding the sales of interests in Cove Point. Income before income taxes recorded by Cove Point for 2021, 2020 and 2019 was $528 million, $511 million and $471 million, respectively. For the periods prior to closing of the GT&S Transaction, earnings attributable to Dominion Energy are presented in discontinued operations. Subsequent to the closing of the GT&S Transaction, earnings attributable to Dominion Energy are presented within earnings from equity method investees in its Consolidated Statements of Income. In 2020, earnings attributable to Dominion Energy of $40 million are presented within earnings from equity method investees in its Consolidated Statements of Income. Dominion Energy recorded distributions from Cove Point of $300 million and $70 million in 2021 and 2020 (after the date of disposal), respectively. Dominion Energy made no contributions to Cove Point in 2021 or 2020 (after the date of disposal). All activity relating to Dominion Energy’s noncontrolling interest in Cove Point is recorded within Contracted Assets. See Note 3 for further information regarding the GT&S Transaction. Atlantic Coast Pipeline In September 2014, Dominion Energy, along with Duke Energy and Southern, announced the formation of Atlantic Coast Pipeline for the purpose of constructing an approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina. Subsidiaries and affiliates of Dominion Energy, Duke Energy and Southern had planned to be customers of the pipeline under 20-year contracts. In March 2020, Dominion Energy completed the acquisition from Southern of its 5% membership interest in Atlantic Coast Pipeline and its 100% ownership interest in Pivotal LNG, Inc., for $184 million in aggregate, subject to certain purchase price adjustments. Pivotal LNG, Inc. includes a 50% noncontrolling interest in JAX LNG. Following completion of the acquisition, Dominion Energy owns a 53% noncontrolling membership interest in Atlantic Coast Pipeline with Duke Energy owning the remaining interest. Atlantic Coast Pipeline continues to be accounted for as an equity method investment as the power to direct the activities most significant to Atlantic Coast Pipeline is shared with Duke Energy. As a result, Dominion Energy has the ability to exercise significant influence, but not control, over the investee. The Atlantic Coast Pipeline Project had been the subject of challenges in federal courts including, among others, challenges of the Atlantic Coast Pipeline Project’s biological opinion and incidental take statement, permits providing right of way crossings of certain federal lands, the Army Corps of Engineers 404 permit, the air permit for a compressor station at Buckingham, Virginia, and the FERC order approving the CPCN. Each of these challenges alleged non-compliance on the part of federal and state permitting authorities and adverse ecological consequences if the Atlantic Coast Pipeline Project was permitted to proceed. Since December 2018, notable developments in these challenges included a stay in December 2018 issued by the U.S. Court of Appeals for the Fourth Circuit and the same court’s July 2019 vacatur of the biological opinion and incidental take statement (which stay and subsequent vacatur halted most project construction activity), the U.S. Court of Appeals for the Fourth Circuit decisions vacating the permits to cross certain federal forests and the air permit for a compressor station at Buckingham, Virginia, the U.S. Court of Appeals for the Fourth Circuit’s remand to the Army Corps of Engineers of Atlantic Coast Pipeline’s Huntington District 404 verification and the U.S. Court of Appeals for the Fourth Circuit’s remand to the National Park Service of Atlantic Coast Pipeline’s Blue Ridge Parkway right-of-way. In June 2019, the Solicitor General of the U.S. and Atlantic Coast Pipeline filed petitions requesting that the Supreme Court of the U.S. hear the case regarding the Appalachian Trail crossing and in June 2020, the Supreme Court of the U.S. ruled in favor of the Atlantic Coast Pipeline, reversing the lower court’s decision and remanding the case back to the U.S. Court of Appeals for the Fourth Circuit. The project also faced new and serious challenges from uncertainty related to NWP 12, specifically, from the decision of the U.S. District Court for the District of Montana in April 2020 vacating an NWP 12 issued by the Army Corps of Engineers, including among other things gas pipelines, followed by a U.S. Court of Appeals for the Ninth Circuit ruling in May 2020 denying a stay of that decision. In July 2020, the Supreme Court of the U.S. issued an order allowing other new oil and gas pipeline projects to use the NWP 12 process pending appeal to the U.S. Court of Appeals for the Ninth Circuit; however, that did not decrease the uncertainty associated with an eventual ruling. The Montana district court decision was viewed as likely to prompt similar challenges in other federal circuit courts related to permits issued under NWP 12, including for the Atlantic Coast Pipeline Project. In July 2020, as a result of ongoing permitting delays, growing legal uncertainties and the need to incur significant capital expenditures to maintain project timing before such uncertainties could be resolved, Dominion Energy and Duke Energy announced the cancellation of the Atlantic Coast Pipeline Project. Dominion Energy recorded equity method earnings (losses) of $(2.3) billion ($(1.8) billion after-tax) for the year ended December 31, 2020, as a result of the determination of the probable abandonment of the Atlantic Coast Pipeline Project in June 2020, and $(20) million ($(14) million after-tax) and $117 million ($118 million after-tax) for the year ended December 31, 2021 and 2019, respectively. In connection with Dominion Energy’s decision to sell substantially all of its gas transmission and storage operations, Dominion Energy has reflected the results of its equity method investment in Atlantic Coast Pipeline as discontinued operations in its Consolidated Statements of Income. As a result of its share of equity losses exceeding its investment Dominion Energy’s Consolidated Balance Sheets at December 31, 2021 and 2020 includes a liability of $113 million and $1.1 billion, respectively, which reflects Dominion Energy’s obligations to Atlantic Coast Pipeline related to its credit facility, through February 2021, and AROs. 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 with a stated maturity date of October 2021 Dominion Energy recorded contributions of $965 million, $107 million and $186 million during 2021, 2020 and 2019, respectively, to Atlantic Coast Pipeline. Dominion Energy expects to incur additional losses from Atlantic Coast Pipeline as it completes wind-down activities. While Dominion Energy is unable to precisely estimate the amounts to be incurred by Atlantic Coast Pipeline, the portion of such amounts attributable to Dominion Energy is not expected to be material to Dominion Energy’s results of operations, financial position or statement of cash flows. DETI provided services to Atlantic Coast Pipeline which totaled $49 million and $103 million in 2020 (prior to closing of the GT&S Transaction) and 2019, respectively, included in discontinued operations in Dominion Energy’s Consolidated Statements of Income. All activity relating to Atlantic Coast Pipeline is recorded within the Corporate and Other segment. Blue Racer In December 2018, Dominion Energy sold its 50% limited partnership interest in Blue Racer for up-front cash consideration of $1.05 billion and additional consideration of $150 million, subject to increase for interest costs effective March 2019, payable upon the purchaser’s availability of cash. In the first quarter of 2019, Dominion Energy received $151 million of additional consideration, including applicable interest, in connection with this sale. In addition, the purchaser agreed to pay additional consideration contingent upon the achievement of certain financial performance milestones of Blue Racer from 2019 through 2021. Blue Racer did not achieve the 2019, 2020 or 2021 financial performance milestones set forth in the sale agreement. All activity relating to Blue Racer is recorded within the Corporate and Other segment. Fowler Ridge In September 2020, Dominion Energy sold its 50% noncontrolling partnership interest in Fowler Ridge to BP and terminated an affiliate’s long-term power, capacity and renewable energy credit contract with Fowler Ridge for a net payment by Dominion Energy of $150 million. The $150 million payment was allocated between the contract termination and sale based on the relative fair value of each using an income approach. The fair value determinations for the payment allocations are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including the amount of future cash flows and discount rate reflecting risks inherent in the future cash flows and market prices. Dominion Energy recognized a loss of $221 million ($165 million after-tax) on the contract termination, included in impairment of assets and other charges in its Consolidated Statements of Income for the year ended December 31, 2020, reflected in the Corporate and Other segment. All activity relating to Fowler Ridge, unless otherwise specified, is recorded within Contracted Assets. Wrangler In September 2019, Dominion Energy entered into an agreement to form Wrangler, a partnership with Interstate Gas Supply, Inc. Wrangler will operate a nonregulated natural gas retail energy marketing business with Dominion Energy contributing its nonregulated retail energy marketing operations and Interstate Gas Supply, Inc. contributing cash. At December 31, 2021 Dominion Energy has a 15% noncontrolling ownership interest in Wrangler, which is accounted for as an equity method investment as Dominion Energy has the ability to exercise significant influence, but not control, over the investee. The initial contribution, consisting of SEMI, closed in December 2019 for which Dominion Energy received $301 million in cash proceeds and a 20% noncontrolling ownership interest in Wrangler with an initial fair value of $75 million estimated using the market approach. This valuation is considered a Level 2 fair value measurement given that it is based on the agreed-upon sales price. In connection with the transaction, Dominion Energy recorded a gain of $147 million, net of a $73 million write-off of goodwill, presented in losses (gains) on sales of assets, and an associated tax expense of $82 million, in the Consolidated Statements of Income for the year ended December 31, 2019. The second contribution, consisting of certain nonregulated natural gas retail energy contracts, closed in November 2020 for which Dominion Energy received $74 million in cash proceeds and retained a 20% noncontrolling ownership interest through its ownership interest in Wrangler in the contracts valued at $13 million using the market approach. This valuation is considered a Level 2 fair value measurement given that it is based on the agreed-upon sales price. In connection with the transaction, Dominion Energy recorded a gain of $64 million presented in losses (gains) on sales of assets, and an associated tax expense of $19 million, in the Consolidated Statements of Income for the year ended December 31, 2020. The final contribution, consisting of Dominion Energy’s remaining nonregulated natural gas retail energy marketing operations, closed in December 2021 for which Dominion Energy received $127 million in cash proceeds and retained a 20% noncontrolling ownership interest in Wrangler with an initial fair value of $23 million estimated using the market approach. This valuation is considered a Level 2 fair value measurement given that it is based on the agreed-upon sales price. In connection with the transaction, Dominion Energy recorded a gain of $87 million, net of a $14 million write-off of goodwill, presented in losses (gains) on sales of assets, and an associated tax expense of $32 million, in the Consolidated Statements of Income for the year ended December 31, 2021. Subsequently in December 2021, Dominion Energy sold 5% of its noncontrolling ownership interest in Wrangler to Interstate Gas Supply, Inc. for $33 million and recorded a gain of $10 million, presented in other income, and an associated tax expense of $3 million, in the Consolidated Statements of Income for the year ended December 31, 2021. At December 31, 2020, $63 million of assets and $15 million of liabilities associated with the remaining nonregulated retail energy marketing operations contributed to Wrangler in December 2021 were classified as held for sale and were included in current assets held for sale and current liabilities held for sale on Dominion Energy’s Consolidated Balance Sheets, respectively. The related disposal group is primarily comprised of customer receivables, goodwill, inventories and account payables. All activity relating to Wrangler is recorded within the Corporate and Other segment. Dominion Privatization In February 2022, Dominion Energy entered into an agreement to form Dominion Privatization, a partnership with Patriot. Dominion Privatization, through its wholly-owned subsidiaries, will maintain and operate electric and gas distribution infrastructure under service concession arrangements with certain U.S. military installations. Under the agreement, Dominion Energy will contribute its existing privatization operations, excluding contracts held by DESC, in South Carolina, Texas, Pennsylvania and Virginia and Patriot will contribute cash. The contribution of the service concession arrangements currently held by Virginia Power requires approval from the Virginia and North Carolina Commissions. Dominion Energy expects to receive cash proceeds totaling $168 million, subject to customary closing adjustments, and a 50% noncontrolling ownership interest in Dominion Privatization following closing of the contributions expected to occur by the end of 2022, contingent on clearance or approval under the Hart-Scott-Rodino Act and other customary closing and regulatory conditions. Dominion Energy expects to recognize gains totaling approximately $150 million ($110 million after-tax) upon closing of the contributions. Dominion Energy’s 50% noncontrolling ownership interest in Dominion Privatization will be accounted for as an equity method investment as Dominion Energy has the ability to exercise significant influence, but not control, over the investee. All activity relating to Dominion Privatization will be recorded within Dominion Energy Virginia.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2021
Property Plant And Equipment [Abstract]
Property, Plant and Equipment	NOTE 10. PROPERTY, PLANT AND EQUIPMENT Major classes of property, plant and equipment and their respective balances for the Companies are as follows: At December 31, 2021 2020 (millions) Dominion Energy Utility: Generation $ 23,378 $ 22,697 Transmission 15,430 14,351 Distribution 28,953 27,311 Storage 455 436 Nuclear fuel 2,306 2,283 General and other 4,373 4,130 Plant under construction 3,898 3,350 Total utility 78,793 74,558 Non-jurisdictional - including plant under construction 1,694 1,225 Nonutility: Nonregulated generation-nuclear 1,773 1,736 Nonregulated generation-solar 2,026 3,268 Nuclear fuel 1,056 1,012 Other-including plant under construction 1,161 1,160 Total nonutility 6,016 7,176 Total property, plant and equipment $ 86,503 $ 82,959 Virginia Power Utility: Generation $ 17,325 $ 16,769 Transmission 11,760 11,000 Distribution 13,621 12,839 Nuclear fuel 1,702 1,709 General and other 912 845 Plant under construction 2,865 2,338 Total utility 48,185 45,500 Non-jurisdictional - including plant under construction 1,694 1,225 Other 11 11 Total property, plant and equipment $ 49,890 $ 46,736 Jointly-Owned Power Stations The Companies proportionate share of jointly-owned power stations at December 31, 2021 is as follows: Bath County Pumped Storage Station (1) North Anna Units 1 and 2 (1) Clover Power Station (1) Millstone Unit 3 (2) Summer Unit 1 (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % 66.7 % Plant in service 1,063 2,532 610 1,353 1,522 Accumulated depreciation (714 ) (1,381 ) (273 ) (522 ) (699 ) Nuclear fuel — 730 — 549 603 Accumulated amortization of nuclear fuel — (576 ) — (406 ) (387 ) Plant under construction 6 178 1 127 76 (1) Units jointly owned by Virginia Power. (2) Unit jointly owned by Dominion Energy. The co-owners are obligated to pay their share of all future construction expenditures and operating costs of the jointly-owned facilities in the same proportion as their respective ownership interest. The Companies report their share of operating costs in the appropriate operating expense (electric fuel and other energy-related purchases, other operations and maintenance, depreciation, depletion and amortization and other taxes, etc.) in the Consolidated Statements of Income. Acquisition of Solar Projects The following table presents acquisitions by Virginia Power of solar projects. Virginia Power has claimed or expects to claim federal investment tax credits on the projects. Project Name Date Agreement Entered Date Agreement Closed Project Location Project Cost (millions (1)] Date of Commercial Operations MW Capacity Gutenberg September 2017 June 2019 North Carolina 142 September 2019 80 Gloucester June 2018 February 2019 Virginia 37 April 2019 20 Grasshopper (2) August 2018 May 2019 Virginia 128 October 2020 80 Chestnut August 2018 May 2019 North Carolina 127 January 2020 75 Ft. Powhatan June 2019 June 2019 Virginia 267 January 2022 150 Belcher (3) June 2019 August 2019 Virginia 164 June 2021 88 Bedford August 2019 November 2019 Virginia 106 November 2021 70 Maplewood October 2019 October 2019 Virginia 185 Expected 2022 120 Rochambeau December 2019 January 2020 Virginia 35 December 2021 20 Pumpkinseed May 2020 May 2020 Virginia 130 Expected 2022 60 Bookers Mill February 2021 June 2021 Virginia 200 Expected 2023 127 (1) Includes acquisition costs. (2) Referred to as Butcher Creek once placed in service. (3) Referred to as Desper once placed in service. The following table presents acquisitions by Dominion Energy of solar projects in addition to the Virginia Power solar projects presented above. Dominion Energy has claimed or expects to claim federal investment tax credits on the projects. Project Name Date Agreement Entered Date Agreement Closed Project Location Project Cost (millions) (1) Date of Commercial Operations MW Capacity Greensville August 2019 August 2019 Virginia $ 127 December 2020 80 Myrtle August 2019 August 2019 Virginia 32 June 2020 15 Seabrook September 2019 September 2019 South Carolina 103 December 2019 72 Wilkinson November 2019 November 2019 North Carolina 153 December 2019 74 Blackville May 2020 May 2020 South Carolina 12 December 2020 7 Denmark May 2020 May 2020 South Carolina 14 December 2020 6 Yemassee May 2020 August 2020 South Carolina 17 January 2021 10 Trask May 2020 October 2020 South Carolina 22 March 2021 12 Hardin I June 2020 June 2020 Ohio 240 Split (2) 150 Madison July 2020 July 2020 Virginia 125 Expected 2023 62 Hardin II August 2020 Expected 2022 Ohio 295 Expected 2023 150 (1) Includes acquisition costs. (2) In addition to the facilities discussed above, Dominion Energy has also entered into various agreements to install solar facilities, primarily at schools in Virginia. As of December 31, 2021, Dominion Energy had placed in service solar facilities with an aggregate generation capacity of 17 MW at a cost of $34 million and anticipates placing additional facilities in service by the end of 2022 with an estimated total projected cost of approximately $30 million and an aggregate generation capacity of 15 MW. Dominion Energy has claimed or expects to claim federal investment tax credits on the projects. Acquisition of Gathering and Processing Assets In March 2020, Wexpro closed on an agreement with a natural gas gathering systems operator to purchase existing natural gas gathering systems including pipelines, compressors and dehydration equipment for total consideration of $38 million. These facilities gather natural gas in Colorado, Utah and Wyoming. In November 2021, Wexpro closed on an agreement with a natural gas gathering systems operator to purchase an existing natural gas gathering system in Wyoming including pipelines, compressors and dehydration equipment for total consideration of $41 million. Non-Wholly-Owned Nonregulated Solar Facilities Sale to Terra Nova Renewable Partners In August 2021, Dominion Energy entered into an agreement with Terra Nova Renewable Partners to sell SBL Holdco, which held Dominion Energy’s 67% controlling interest in certain nonregulated solar projects for consideration of $456 million, subject to customary closing adjustments, with the amount of cash reduced by the amount of SBL Holdco’s debt outstanding at closing. The sale was contingent on clearance or approval under the Hart-Scott-Rodino Act and by FERC as well as other customary closing and regulatory conditions. In September 2021, the waiting period under the Hart-Scott-Rodino Act expired and in October 2021, FERC approved the proposed sale. In December 2021, the transaction closed and Dominion Energy recorded a gain of $19 million ($15 million after-tax) in losses (gains) on sales of assets in its Consolidated Statements of Income (reflected in the Corporate and Other segment). Except as specifically identified, all activity related to SBL Holdco is recorded within Contracted Assets. Sale to Clearway In August 2021, Dominion Energy entered an agreement with Clearway to sell its 50% controlling interest in Four Brothers and Three Cedars for $335 million in cash, subject to customary closing adjustments. The transaction was contingent on clearance or approval under the Hart-Scott-Rodino Act and by FERC as well as other customary closing and regulatory conditions. In October 2021, the waiting period under the Hart-Scott-Rodino Act expired. In December 2021, the transaction closed and Dominion Energy recorded a loss of $229 million ($176 million after-tax) in losses (gains) on sales of assets in its Consolidated Statements of Income (reflected in the Corporate and Other segment), primarily associated with the derecognition of noncontrolling interest. Except as specifically identified, all activity related to Four Brothers and Three Cedars is recorded within Contracted Assets. Impairment In the third quarter of 2020, Dominion Energy performed a strategic review of its long-term intentions for its contracted nonregulated solar generation assets in partnerships outside of its core electric service territories in consideration of the impact of the VCEA and Dominion Energy’s decision to sell substantially all of its gas transmission and storage operations. Based on an evaluation of Dominion Energy’s interests in these long-lived assets for recoverability under a probability weighted approach, Dominion Energy determined the assets were impaired. As a result of this evaluation, Dominion Energy recorded a charge of $ 665 million ($ 293 million after-tax attributable to Dominion Energy and $ 267 million attributable to noncontrolling interest) in impairment of assets and other charges in its Consolidated Statements of Income (reflected in the Corporate and Other segment) for the year ended December 31, 2020 to adjust the property, plant and equipment down to its estimated fair value of $ 1.4 billion. The fair value was estimated using an income approach. The valuation is considered a Level 3 fair value measurement due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risks inherent in the future cash flows and market prices. Virginia Power CCRO Utilization In 2021, Virginia Power wrote off $318 million, primarily to accumulated depreciation, representing the utilization of a CCRO in accordance with the GTSA in connection with the settlement of the 2021 Triennial Review. See Note 13 for additional information.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2021
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	NOTE 11. GOODWILL AND INTANGIBLE ASSETS Goodwill The changes in Dominion Energy’s carrying amount and segment allocation of goodwill are presented below: Dominion Energy Virginia Gas Distribution Dominion Energy South Carolina Contracted Assets Corporate and Other Total (millions) Dominion Energy Balance at December 31, 2019 (1) $ 2,106 $ 3,512 $ 1,521 $ 242 $ 14 $ 7,395 Contribution to Wrangler (2) — — — — (14 ) (14 ) Balance at December 31, 2020 (1) $ 2,106 $ 3,512 $ 1,521 $ 242 $ — $ 7,381 Acquisition of Birdseye (3) — — — 24 — 24 Balance at December 31, 2021 (1) $ 2,106 $ 3,512 $ 1,521 $ 266 $ — $ 7,405 (1) Goodwill amounts do not contain any accumulated impairment losses. (2) See Note 9 for additional information including amounts reclassified to held for sale at December 31, 2020. (3) See Note 3 for more information. Other Intangible Assets The Companies’ other intangible assets are subject to amortization over their estimated useful lives. Dominion Energy’s amortization expense for intangible assets was $79 million, $69 million and $95 million for 2021, 2020 and 2019, respectively. In 2021, Dominion Energy acquired $311 million of intangible assets, primarily representing RGGI allowances and software, with an estimated weighted-average amortization period of approximately 7 years. Amortization expense for Virginia Power’s intangible assets was $31 million, $28 million and $30 million for 2021, 2020 and 2019, respectively. In 2021, Virginia Power acquired $276 million of intangible assets, primarily representing RGGI allowances and software, with an estimated weighted-average amortization period of 7 years. The components of intangible assets are as follows: 2021 2020 At December 31, Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (millions) Dominion Energy Software, licenses and other (1) $ 1,459 $ 675 $ 1,295 $ 530 Virginia Power Software, licenses and other (1) $ 685 $ 290 $ 482 $ 148 (1) Includes $158M of RGGI allowances purchased Annual amortization expense for these intangible assets is estimated to be as follows: 2022 2023 2024 2025 2026 (millions) Dominion Energy $ 72 $ 58 $ 50 $ 42 $ 28 Virginia Power $ 29 $ 23 $ 20 $ 16 $ 9

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Regulatory Assets and Liabilities	NOTE 12. REGULATORY ASSETS AND LIABILITIES Regulatory assets and liabilities include the following: At December 31, 2021 2020 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 251 $ — Deferred project costs and DSM programs for gas utilities (2) 53 35 Unrecovered gas costs (3) 191 78 Deferred rider costs for Virginia electric utility (4) 72 98 Ashpond and landfill closure costs (5) 193 — Deferred nuclear refueling outage costs (6) 79 53 NND Project costs (7) 138 138 PJM transmission rates (8) 7 71 Deferred early plant retirement charges (9) 226 — Derivatives (10) 112 33 Other 170 193 Regulatory assets-current 1,492 699 Unrecognized pension and other postretirement benefit costs (11) 548 1,363 Deferred rider costs for Virginia electric utility (4) 489 311 Deferred project costs for gas utilities (2) 675 632 Interest rate hedges (12) 899 1,042 AROs and related funding (13) 329 331 Cost of reacquired debt (14) 10 245 NND Project costs (7) 2,226 2,364 Ash pond and landfill closure costs (5) 2,223 2,301 Deferred cost of fuel used in electric generation (1) 409 — Deferred early plant retirement charges (9) 226 — Other 609 544 Regulatory assets-noncurrent 8,643 9,133 Total regulatory assets $ 10,135 $ 9,832 Regulatory liabilities: Deferred cost of fuel used in electric generation (1) $ — $ 58 Provision for future cost of removal and AROs (15) 181 183 Reserve for refunds and rate credits to electric utility customers (16) 420 128 Reserve for future credits to Virginia electric customers (17) — 120 Income taxes refundable through future rates (18) 153 124 Monetization of guarantee settlement (19) 67 67 Commodity derivatives (10) 55 9 Other 110 120 Regulatory liabilities-current 986 809 Income taxes refundable through future rates (18) 4,260 4,376 Provision for future cost of removal and AROs (15) 2,331 2,150 Nuclear decommissioning trust (20) 2,158 1,719 Monetization of guarantee settlement (19) 831 903 Reserve for refunds and rate credits to electric utility customers (16) 448 540 Unrecognized pension and other postretirement benefit costs ( 1 1) 200 66 Overrecovered other postretirement benefit costs (2 1 ) 105 111 Other 380 322 Regulatory liabilities-noncurrent 10,713 10,187 Total regulatory liabilities $ 11,699 $ 10,996 (1) Reflects deferred fuel expenses for the Virginia, North Carolina and South Carolina jurisdictions of Dominion Energy’s electric generation operations. (2) Primarily reflects amounts expected to be collected from or owed to gas customers in Dominion Energy’s service territories associated with current and prospective rider projects, including CEP, PIR and pipeline integrity management. See Note 13 for more information . (3) Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority (4) Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information (5) Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on (6) 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. (7) Reflects expenditures by DESC associated with the NND Project, which pursuant to the SCANA Merger Approval Order, will be recovered from DESC electric service customers over a 20-year period ending in 2039. See Note 3 for more information (8) Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter.‌ (9) Reflects amounts from the early retirements of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for additional information (10) 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 (11) 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 rate-regulated subsidiaries (12) Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 27 years as of December 31, 2021 (13) Represents deferred depreciation and accretion expense related to legal obligations associated with the future retirement of generation, transmission and distribution properties. The AROs primarily relate to DESC’s electric generating facilities, including Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately 105 years (14) In 2021, DESC recorded a charge of $237 million ($178 million after-tax) in impairment of assets and other charges, reflected in the Corporate and Other segment, to write-off the balance of a regulatory asset that is no longer probable of recovery under the settlement agreement approved in DESC’s retail electric base rate case. (15) Rates charged to customers by Dominion Energy’s 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 (16) Reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period effective February 2019, in connection with the SCANA Merger Approval Order. See Notes 3 and 13 for more information (17) Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information. (18) Amounts recorded to pass the effect of reduced income taxes from the 2017 Tax Reform Act to customers in future periods, which will primarily 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 (19) Reflects amounts to be refunded to DESC electric service customers over a 20-year period ending in 2039 associated with the monetization of a bankruptcy settlement agreement. See Note 3 for more information. (20) 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, as applicable) for the future decommissioning of Dominion Energy’s utility nuclear generation stations, in excess of the related AROs. (21) Reflects a regulatory liability for the collection of postretirement benefit costs allowed in rates in excess of expense incurred. At December 31, 2021 2020 (millions) Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 131 $ — Deferred rider costs (2) 72 98 Ash pond and landfill closure costs (3) 193 — Deferred nuclear refueling outage costs (4) 79 53 PJM transmission rates (5) 7 71 Deferred early plant retirement charges (6) 226 — Derivatives (7) 105 40 Other 37 33 Regulatory assets-current 850 295 Deferred rider costs (2) 489 311 Interest rate hedges (8) 604 733 Ash pond and landfill closure costs (3) 2,223 2,301 Deferred cost of fuel used in electric generation (1) 409 — Deferred early plant retirement charges (6) 226 — Other 179 164 Regulatory assets-noncurrent 4,130 3,509 Total regulatory assets $ 4,980 $ 3,804 Regulatory liabilities: Deferred cost of fuel used in electric generation (1) $ — $ 58 Provision for future cost of removal (9) 154 152 Reserve for refunds to Virginia electric customers (10) 306 — Reserve for future credits to Virginia electric customers (11) — 120 Income taxes refundable through future rates (12) 63 54 Derivatives (7) 51 8 Other 73 33 Regulatory liabilities-current 647 425 Income taxes refundable through future rates (12) 2,335 2,404 Nuclear decommissioning trust (13) 2,158 1,719 Provision for future cost of removal (9) 1,043 980 Deferred cost of fuel used in electric generation (1) — 54 Reserve for refunds to Virginia electric customers (10) 25 — Other 179 181 Regulatory liabilities-noncurrent 5,740 5,338 Total regulatory liabilities $ 6,387 $ 5,763 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s generation operations (2) Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information (3) Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on uncollected expenditures once expenditures have been made. See Note 13 for additional information. (4) 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 (5) Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter. (6) Reflects amounts from the early retirement of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for more information (7) For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers (8) Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 25 years as of December (9) Rates charged to customers by Virginia Power's regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement (10) Reflects amounts to be refunded to jurisdictional retail electric customers in Virginia associated with the settlement of the 2021 Triennial Review. See Note 13 for additional information (11) Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information (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 At December 31, 2021, Dominion Energy and Virginia Power regulatory assets include $4.4 billion and $3.0 billion, respectively, on which they do not expect to earn a return during the applicable recovery period. With the exception of certain items discussed above, the majority of these expenditures are expected to be recovered within the next two years.

Regulatory Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2021
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 regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations. Other Regulatory Matters Virginia Regulation Regulation Act and Grid Transformation and Security Act of 2018 The Regulation Act enacted in 2007 instituted a cost-of-service rate model, ending Virginia’s planned transition to retail competition for electric supply service to most classes of customers. The Regulation Act authorizes stand-alone rate adjustment clauses for recovery of costs for new generation projects, FERC-approved transmission costs, underground distribution lines, environmental compliance, conservation and energy efficiency programs, renewable energy programs and nuclear license renewals, and also contains statutory provisions directing Virginia Power to file annual fuel cost recovery cases with the Virginia Commission. If the Virginia Commission’s future rate decisions, including actions relating to Virginia Power’s rate adjustment clause filings, differ materially from Virginia Power’s expectations, it may adversely affect its results of operations, financial condition and cash flows. The GTSA reinstated base rate reviews commencing with the 2021 Triennial Review. In the triennial review proceedings, earnings that are more than 70 basis points above the utility’s authorized ROE that might have been refunded to customers Virginia 2020 Legislation In April 2020, the Governor of Virginia signed into law the VCEA, which along with related legislation forms a comprehensive framework affecting Virginia Power’s operations. The VCEA replaces Virginia’s voluntary renewable energy portfolio standard for Virginia Power with a mandatory program setting annual renewable energy portfolio standard requirements based on the percentage of total electric energy sold by Virginia Power, excluding existing nuclear generation and certain new carbon-free resources, reaching 100 % by the end of 2045. The VCEA includes related requirements concerning deployment of wind, solar and energy storage resources, as well as provides for certain measures to increase net-metering, including an allocation for low-income customers, incentivizes energy efficiency programs and directs Virginia to participate in a carbon trading program. While the legislation affects several portions of Virginia Power’s operations, key provisions of the GTSA remain in effect, including the triennial review structure and timing, the use of the CCRO and the $ 50 million cap on revenue reductions in the first triennial review proceeding. Key provisions of the VCEA and related legislation passed include the following: • Fossil Fuel Electric Generation : The legislation mandates Chesterfield Power Station Units 5 & 6 and Yorktown Power Station Unit 3 to be retired by the end of 2024, Altavista, Southampton and Hopewell to be retired by the end of 2028 and Virginia Power’s remaining fossil fuel units to be retired by the end of 2045, unless the retirement of such generating units will compromise grid reliability or security. The legislation also imposed a temporary moratorium on CPCNs for fossil fuel generation, unless the resources are needed for grid reliability. This temporary moratorium concluded in January 2022. In addition, the Virginia Commission shall determine the amortization period for recovery of any appropriate costs due to the early retirement of any electric generation facilities, which could result in the reversal of previous retirement costs deemed recovered during the review period ending 2020. As discussed in Note 2, Virginia Power had recorded charges for early retirement of certain coal- and oil-fired generating units in the first quarters of 2020 and 2019. Virginia Power also revised the depreciable lives of Altavista, Southampton and Hopewell for the mandated retirement to the end of 2028, which will not have a material impact to Virginia Power’s results of operations or cash flows given the existing regulatory framework. • Renewable Generation: The legislation provides a detailed renewable energy portfolio standard to achieve 100% zero-carbon generation by the end of 2045, excluding existing nuclear generation and certain new carbon-free resources. Components include requirements to petition the Virginia Commission for approval to construct or acquire new generating capacity to reach 16.1 GW of installed solar and onshore wind by the end of 2035, which includes specific requirements for utility-scale solar of 3.0 GW by the end of 2024, up to 15.0 GW by the end of 2035 and 1.1 GW of small-scale solar by the end of 2035. The legislation deems 2.7 GW of energy storage, including up to 800 MW for any one project which may include a pumped storage facility, by the end of 2035 to be in the public interest. The legislation also deems the construction or purchase of an offshore wind facility constructed off the Virginia coast with a capacity of up to 5.2 GW before 2035 to be in the public interest and provides certain presumptions facilitating cost recovery. The costs of such a facility constructed by the utility with a capacity between 2.5 and 3.0 GW will be presumed reasonably and prudently incurred if the Virginia Commission finds that the project meets competitive procurement requirements, the projected cost of the facility does not exceed a specified industry benchmark and the utility commences construction by the end of 2023 or has a plan for the facility to be in service by the end of 2027. Projects to meet these requirements are subject to approval by the Virginia Commission. • Energy Efficiency: The legislation includes an energy efficiency target of 5% energy savings, as measured from a 2019 baseline, through verifiable energy efficiency programs by the end of 2025 with future targets to be set by the Virginia Commission. Virginia Power has the opportunity to offset the lost revenues with margins on program spend if certain targets are achieved and can also seek recovery of the lost revenues associated with energy efficiency programs if such reductions are found to have caused Virginia Power to earn more than 50 basis points below a fair rate of return on its rates for generation and distribution services • Carbon trading program : The legislation directs Virginia to participate in a market-based carbon trading program consistent with RGGI through 2050. In January 2022, the Governor of Virginia issued an executive order which puts directives in place to start the withdrawal of Virginia from RGGI. All costs of the carbon trading program are recoverable through an environmental rider. • Low-income customers : The legislation includes the establishment of a percentage of income payment program to be administered by the Virginia Department of Housing and Community Development and the Virginia Department of Social Services. To fund the program, Virginia Power will remit amounts collected from customers under a universal service fee established and set by the Virginia Commission. As such, this program will not affect Virginia Power’s results of operations, financial position or cash flows. In December 2020, the Virginia Commission issued a final order confirming a revenue requirement of $93 million related to this program. Implementation details and the effective date of the program will be established in future legislation prior to collection of fees from customers. Virginia Power is incurring and expects to incur significant costs, including capital expenditures, to comply with the legislative requirements discussed above. The legislation allows for cost recovery under the existing or modified regulatory framework through rate adjustment clauses, rates for generation and distribution services or Virginia Power’s fuel factor, as approved by the Virginia Commission. Costs allocated to the North Carolina jurisdiction will be recovered, subject to approval by the North Carolina Commission, in accordance with the existing regulatory framework. 2021 Triennial Review In March 2021, Virginia Power filed its base rate case and accompanying schedules in support of the 2021 Triennial Review. In its filing, Virginia Power did not request an increase in base rates for generation and distribution services and proposed that base rates remain at their existing level. Virginia Power’s earnings test analysis, as filed, demonstrated it earned a combined ROE of 10.85% on its generation and distribution services for the test period, before accounting for forgiven customer balances. Pursuant to Virginia legislation, forgiven customer balances were excluded from the cost of service in determining test period revenues as part of the 2021 Triennial Review. To the extent that the Virginia Commission determine d total earnings for the test period to be above Virginia Power’s authorized earnings band, the forgiven balance amounts are offset against the available revenues in the determination of any customer bill credits, or utilization of a CCRO. Test period earnings may be further reduced by Virginia Commission approved investment amounts in qualifying solar or wind generation facilities or electric distribution grid transformation projects that Virginia Power elects to include as a CCRO under the GTSA. In its filing, Virginia Power elected to utilize $ 26 million of the CVOW Pilot P roject investment as a CCRO to offset available revenues. Virginia Power ha d contingently elected to offset additional available revenues, if any, determined by the Virginia Commission for earnings sharing with additional Virginia Commission approved qualifying CCRO investments. The Virginia Commission also authorize d an ROE for Virginia Power that is applied to Virginia Power’s riders prospectively and that was also utilized to measure base rate earnings as of January 1, 2021. Virginia Power ha d requested authorization of an ROE of 10.8 % based on Virginia Power’s current cost of equity. Pursuant to the Regulation Act, Virginia Power’s authorized ROE shall not be set lower than the average of either (i) the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., with certain limitations as described in the Regulation Act, or (ii) the authorized returns that are set by the applicable regulatory commissions for the same select peer group. In May 2021, Virginia Power filed supplemental testimony to reflect updated test period earnings, including an earned ROE of 10.42 %, before accounting for forgiven customer balances, and that no amount of eligible CCRO is necessary to be elected to be utilized. In 2020, Virginia Power recorded a net charge of $130 million related to the use of a CCRO in accordance with the GTSA, included in impairment of assets and other charges (benefits) in its Consolidated Statements of Income (reflected in the Corporate and Other segment) for benefits expected to be provided to jurisdictional customers as a result of the 2021 Triennial Review as well as the impact on certain non-jurisdictional customers which follow Virginia Power’s jurisdictional customer rate methodology. In 2021, Virginia Power recorded a benefit of $130 million ($97 million after-tax) in impairment of assets and other charges (benefits) in its Consolidated Statements of Income (reflected in the Corporate and Other segment) to adjust its reserve related to the use of a CCRO in accordance with the GTSA. Subsequently, in October 2021, Virginia Power, the Virginia Commission staff and other parties filed a comprehensive settlement agreement with the Virginia Commission for approval. The comprehensive settlement agreement provides for $330 million in one-time refunds to customers made up of $255 million over a 6-month period and $75 million over three years, a $50 million going-forward base rate reduction and an authorized ROE of 9.35%. Additionally, Virginia Power has agreed to utilize $309 million of qualifying CCRO investments in the CVOW Pilot Project, deployment of AMI and a Customer Information Platform to offset available earnings and to amortize through 2023 the early retirement charges for coal- and oil-fired generation units recorded in 2019 and 2020. In November 2021, the Virginia Commission approved the comprehensive settlement agreement. In connection with the settlement agreement, Virginia Power recorded a $356 million ($265 million after-tax) charge for refunds to be provided to customers in operating revenues in its Consolidated Statements of Income as well as a $549 million ($409 million after-tax) benefit primarily from the establishment of a regulatory asset associated with the early retirements of certain coal- and oil-fired generating units and a $318 million ($237 million after-tax) charge for CCRO benefits provided to customers in impairment of assets and other charges (benefits) in its Consolidated Statements of Income (reflected in the Corporate and Other segment). The amounts recorded reflect the impact related to jurisdictional customers as a result of the 2021 Triennial Review as well as the impact on certain non-jurisdictional customers which follow Virginia Power’s jurisdictional customer rate methodology. Utility Disconnection Moratorium In November 2020, legislation was enacted in Virginia relating to the moratorium on utility disconnections during the COVID-19 pandemic and resulted in Virginia Power forgiving Virginia jurisdictional retail electric customer balances that were more than 30 days past due as of September 30, 2020. As a result, Virginia Power recorded a charge of $127 million ($94 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income (reflected in the Corporate and Other segment) in 2020. In connection with the Virginia 2021 budget process, in the first quarter of 2021 Virginia Power recorded a charge of $76 million ($56 million after-tax) in impairment of assets and other charges (benefits) in its Consolidated Statements of Income for Virginia jurisdictional retail electric customer balances that were more than 30 days past due as of December 31, 2020 that Virginia Power is required to forgive. For the purposes of Virginia Power’s 2021 Triennial Review, these charges were excluded from Virginia Power’s cost of service for purposes of determining any test period earnings and determining any future rates. To the extent that the Virginia Commission determined total earnings for the test period were above Virginia Power’s authorized earnings band, the forgiven balance amounts were offset against the excess earnings in the determination of any customer bill credits, or utilization of a CCRO, as part of the 2021 Triennial Review discussed above. Virginia Fuel Expenses In May 2021, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $1.4 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2021 and $72 million of estimated net under-recovered balances through June 30, 2021. In June 2021, the Virginia Commission approved the annual fuel factor. GTSA Filing In June 2021, Virginia Power filed a petition with the Virginia Commission for approval of a revised plan for electric distribution grid transformation projects as authorized by the GTSA. The plan includes 14 projects covering six components: (i) smart meters; (ii) customer information platform; (iii) grid improvement projects; (iv) physical and cyber security; (v) telecommunications infrastructure and (vi) customer education (Phase II). For Phase II, the total proposed capital investment during 2022 – 2023 is $667 million and the proposed operations and maintenance investment is $110 million. In January 2022, the Virginia Commission approved the petition. Renewable Generation Projects In May 2020 and July 2020, Virginia Power entered into and closed on separate agreements to acquire Grassfield Solar, Norge Solar and Sycamore Solar. The projects are expected to cost approximately $170 million in aggregate once constructed, including the initial acquisition cost. The facilities are expected to generate 82 MW combined and be placed into service in 2022. In October 2020, Virginia Power filed an application with the Virginia Commission for CPCNs to construct and operate these projects as part of its efforts to meet the renewable generation development requirements under VCEA. In April 2021, the Virginia Commission approved the application. In September 2021, Virginia Power filed a petition with the Virginia Commission for CPCNs to construct and operate 13 utility-scale projects totaling approximately 661 MW of solar generation and 70 MW of energy storage as part of its efforts to meet the renewable generation development requirements under the VCEA. The projects are expected to cost approximately $1.4 billion in the aggregate, excluding financing costs, and be placed into service between 2022 and 2023. This matter is pending. In November 2021, Virginia Power filed an application with the Virginia Commission requesting approval and certification of the Virginia Facilities component of the CVOW Commercial Project. The onshore Virginia Facilities have an estimated cost of approximately $1.1 billion, excluding financing costs, which is included within the overall cost of the CVOW Commercial Project. In addition, Virginia Power requested approval from the Virginia Commission to enter into financial hedges with U.S. financial institutions to mitigate the foreign currency exchange risk associated with certain supplier contracts associated with the CVOW Commercial Project. This matter is pending. Nuclear Life Extension Program In October 2021, Virginia Power filed a petition with the Virginia Commission requesting a determination that it is reasonable and prudent for Virginia Power to pursue a nuclear life extension program to extend the operating licenses of Surry and North Anna and to carry out projects to upgrade or replace systems and equipment necessary to continue to safely and reliably operate these nuclear power stations. The nuclear life extension program is expected to cost approximately $3.9 billion, excluding financing costs. This matter is pending. Riders The significant riders associated with various Virginia Power projects are as follows: Rider Name Application Date Approval Date Rate Year Beginning Total Revenue Requirement (millions) Increase (Decrease) Over Previous Year (millions) Rider B June 2020 February 2021 April 2021 24 (8 ) Rider B June 2021 February 2022 April 2022 16 (8 ) Rider BW October 2020 July 2021 September 2021 113 14 Rider BW October 2021 Pending September 2022 145 32 Rider BW October 2021 Pending September 2023 120 (25 ) Rider CCR February 2021 October 2021 December 2021 216 N/A Rider CE (1) October 2020 April 2021 June 2021 10 N/A Rider CE (2) September 2021 Pending May 2022 71 61 Rider E January 2021 September 2021 November 2021 67 (18 ) Rider E January 2022 Pending November 2022 101 34 Rider GT August 2021 Pending June 2022 56 N/A Rider GV June 2020 February 2021 April 2021 153 21 Rider GV June 2021 December 2021 April 2022 142 (11 ) Rider GV June 2021 December 2021 April 2023 127 (15 ) Rider OSW November 2021 Pending September 2022 79 N/A Rider R June 2020 February 2021 April 2021 58 14 Rider R June 2021 Pending April 2022 59 1 Rider R June 2021 Pending April 2023 55 (4 ) Rider RGGI (3) December 2020 August 2021 September 2021 168 N/A Rider RGGI (4) December 2021 Withdrawal pending Rider RPS December 2020 July 2021 August 2021 13 N/A Rider RPS December 2021 Pending September 2022 140 127 Rider S June 2020 February 2021 April 2021 194 (1 ) Rider S June 2021 February 2022 April 2022 192 (2 ) Rider S June 2021 February 2022 April 2023 191 (1 ) Rider SNA (5) October 2021 Pending September 2022 109 N/A Rider T1 (6) May 2021 August 2021 September 2021 874 (190 ) Rider U (7) June 2020 February 2021 April 2021 80 28 Rider U (8) June 2021 Pending April 2022 96 16 Rider US-2 October 2020 July 2021 September 2021 9 — Rider US-2 October 2021 Pending September 2022 11 2 Rider US-3 July 2020 March 2021 June 2021 38 10 Rider US-3 August 2021 Pending June 2022 50 12 Rider US-4 July 2020 March 2021 June 2021 10 3 Rider US-4 August 2021 Pending June 2022 15 5 Rider W June 2020 February 2021 April 2021 120 14 Rider W June 2021 February 2022 April 2022 121 1 DSM Riders (9) December 2020 September 2021 October 2021 74 14 DSM Riders (10) December 2021 Pending September 2022 91 17 (1) Associated with Grassfield Solar, Norge Solar and Sycamore Solar. (2) Associated with solar generation and energy storage projects requested for approval in September 2021, solar generation projects approved in April 2021 and certain small-scale solar projects. (3) In August 2021, the Virginia Commission issued an order granting reconsideration and suspended its order approving the revenue requirement. In November 2021, the Virginia Commission lifted the suspension of the order. In February 2022, a party filed an appeal to the Supreme Court of Virginia challenging the Virginia Commission’s order. (4) In January 2022, Virginia Power filed a motion to withdraw its application as a result of the announcement by the Governor of Virginia that he intends to withdraw Virginia from RGGI. Virginia Power expects to file an updated application to recover its actual and projected RGGI compliance costs informed by these developments at the appropriate time. (5) Virginia Power also requested approval of cost recovery of approximately $1.2 billion through Rider SNA for the first phase of nuclear life extension program which includes investments through 2024. (6) Consists of $493 million for the (7) Consists of $44 million for previously approved phases and $36 million for phase five costs for Rider U. (8) Consists of $61 million for previously approved phases and $35 million for phase six costs for Rider U. (9) Associated with an additional 10 new energy efficiency programs and one new demand response DSM program for five years, subject to future extension, with a $162 million cost cap. (10) Associated with an additional nine new energy efficiency programs with a $140 million cost cap, with the ability to exceed the cost cap by no more than 15%. Electric Transmission Projects Significant Virginia Power electric transmission projects approved or applied for are as follows: Description and Location of Project Application Date Approval Date Type of Line Miles of Lines Cost Estimate (millions) Bristers-Ladysmith Rebuild Project in the Counties of Fauquier, Stafford, Spotsylvania and Caroline, Virginia May 2020 February 2021 500 kV 37 110 Relocate and replace a transmission line underground between the Tysons substation and the future Spring Hill substation September 2020 June 2021 230 kV < 1 30 Rebuild an existing transmission line and install new line adjacent thereto in the Counties of New Kent, King William, King and Queen, Essex and Richmond, Virginia October 2020 December 2021 230 kV 41 100 Rebuild Clubhouse-Dry Bread Line and Dry Bread-Lakeview Line in Greensville County, Virginia November 2020 July 2021 230 kV 13 20 Rebuild transmission lines and related projects in the Counties of York and James City and the City of Williamsburg, Virginia January 2021 September 2021 230 kV 11 30 Elmont-Ladysmith rebuild and related projects in the Counties of Hanover and Caroline, Virginia April 2021 Pending 500 kV 26 95 Beaumeade-Belmont reconductor and rebuild projects in the County of Loudoun, Virginia May 2021 February 2022 230 kV 7 15 Extension to Cloud Switching Station and Easters Switching Station in the County of Mecklenburg, Virginia June 2021 February 2022 230 kV 15 105 Rebuild transmission lines and related projects in the City of Staunton and County of Augusta, Virginia November 2021 Pending 230 kV 21 45 Build new DTC substation and line loop in the County of Loudoun, Virginia December 2021 Pending 230 kV 1 105 Build new Aviator substation and line loop in the County of Loudoun, Virginia February 2022 Pending 230 kV 1 80 In November 2013, the Virginia Commission issued an order granting Virginia Power a CPCN to construct approximately 7 500 20 230 North Carolina Regulation Virginia Power North Carolina Base Rate Case In March 2019, Virginia Power filed its base rate case and schedules with the North Carolina Commission. Virginia Power proposed a non-fuel, base rate increase of $27 million effective November 1, 2019 on an interim basis subject to refund, with any permanent rates ordered by the North Carolina Commission effective January 1, 2020. The base rate increase was proposed to recover the significant investments in generation, transmission and distribution infrastructure for the benefit of North Carolina customers. Virginia Power presented an earned return of 7.52% based upon a fully-adjusted test period, compared to its authorized 9.90% return, and proposed a 10.75% ROE. In September 2019, Virginia Power revised its filing to reduce the non-fuel base rate increase to $24 million. In January 2020, the North Carolina Commission approved a 9.75% ROE and disallowed certain costs associated with coal ash remediation at Chesterfield power station. In February 2020, the North Carolina Commission issued its final order relating to base rates. In July 2020, Virginia Power filed a notice of appeal and exceptions to the Supreme Court of North Carolina, arguing that the North Carolina Commission committed reversible error on certain issues relating to the ratemaking treatment of certain coal ash remediation costs. This matter is pending. Virginia Power North Carolina Fuel Filing In August 2021, Virginia Power submitted its annual filing to the North Carolina Commission to adjust the fuel component of its electric rates. Virginia Power updated its filing in October 2021 to reflect the increased commodity cost of fuel and proposed a total $26 million increase to the fuel component of its electric rates for the rate year beginning February 1, 2022. In January 2022, the North Carolina Commission approved the filing. PSNC Base Rate Case In April 2021, PSNC filed its general rate case application and schedules with the North Carolina Commission. PSNC proposed a non-fuel, base rate increase of $53 million to be effective November 1, 2021. After considering the benefits of the 2017 Tax Reform Act, the net revenue increase to customers would be approximately $42 million. The base rate increase was proposed to recover the significant investment in infrastructure to serve a growing customer base, improve safety and reliability of the transmission and distribution system and enhance energy efficiency and sustainability. The proposed rates would provide for an ROE of 10.25% compared to the currently authorized ROE of 9.7%. In October 2021, PSNC, the North Carolina Commission public staff and certain other parties of record filed a stipulation of settlement with the North Carolina Commission for approval. The stipulation of settlement provides for a non-fuel, base rate increase of $29 million effective November 1, 2021, based on an ROE of 9.60%. The net revenue increase to customers, after considering the amortization of the previously deferred benefits of the 2017 Tax Reform Act, would be $4 million in the initial rate year, $23 million for the following rate year and then $26 million beginning for the third through fifth rate years. In addition, the stipulation of settlement provides for the recovery, over four years, of $106 million of operation and maintenance costs which PSNC has incurred and deferred through June 2021 to comply with federal standards for pipeline integrity and safety. In November 2021, PSNC implemented temporary rates consistent with the stipulation of settlement. In December 2021, a revised stipulation of settlement was filed with the North Carolina Commission adjusting the net revenue increase to customers, after considering the amortization of the previously deferred benefits of the 2017 Tax Reform Act, to $6 million in the initial rate year, $25 million for the following rate year and $27 million beginning for the third through fifth rate years. In January 2022, the North Carolina Commission approved the revised stipulation of settlement without modification and issued its final order. Pipeline Integrity and Safety Program The North Carolina Commission has authorized PSNC to use a tracker mechanism to recover the incurred capital investment and associated costs of complying with federal standards for pipeline integrity and safety requirements that are not in current base rates. In August 2021, the North Carolina Commission approved PSNC’s request to increase the integrity management annual revenue requirement to $34 million, an increase of $1 million over its previous filing, effective September 2021. Rider D Rider D allows PSNC to recover from customers all prudently incurred gas costs and certain related uncollectible expenses as well as losses on negotiated gas and transportation sales. In September 2021, PSNC submitted a filing with the North Carolina Commission for a $61 million gas cost increase. The North Carolina Commission approved the filing in September 2021 with rates effective October 2021. In November 2021, PSNC submitted a filing with the North Carolina Commission for a $49 million gas cost increase and a $15 million increase in the customers deferred account. The North Carolina Commission approved the filing in December 2021 with rates effective December 2021. South Carolina Regulation South Carolina Electric Base Rate Case In August 2020, DESC filed its retail electric base rate case and schedules with the South Carolina Commission. DESC proposed a non-fuel, base rate increase of $178 million, or 7.75%, based on an adjusted test year data, effective on or after the first billing cycle of March 2021. The base rate increase was proposed to recover the significant investment in assets and operating resources required to serve an expanding customer base, maintain the safety, reliability and efficiency of DESC’s system and meet increasingly stringent reliability, security and environmental requirements for the benefit of South Carolina customers. DESC presented an earned ROE of 5.90% based upon a fully-adjusted test period. The proposed rates would provide for an earned ROE equal to the current authorized earned ROE of 10.25% established in the previous rate case in 2012. In January 2021, the South Carolina Commission approved a proposal made by the South Carolina Office of Regulatory Staff, and agreed to by DESC and other intervenors, to stay the base rate case due to the current economic conditions and to allow the parties more time to negotiate a settlement with a final order to be issued no later than August 2021. In July 2021, DESC, the South Carolina Office of Regulatory Staff and other parties of record filed a comprehensive settlement agreement with the South Carolina Commission for approval. The comprehensive settlement agreement provides for a non-fuel, base rate increase of $62 million (resulting in a net increase of $36 million after considering an accelerated amortization of certain excess deferred income taxes) commencing with bills issued on September

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	NOTE 14. ASSET RETIREMENT OBLIGATIONS AROs represent obligations that result from laws, statutes, contracts and regulations related to the eventual retirement of certain of the Companies’ long-lived assets. The Companies AROs are primarily associated with the decommissioning of their nuclear generation facilities and ash pond and landfill closures. The Companies have also identified , but not recognized, AROs related to the retirement of Dominion Energy’s storage wells in its underground natural gas storage network, certain The changes to AROs during 2020 and 2021 were as follows: Amount (millions) Dominion Energy AROs at December 31, 2019 $ 5,184 Obligations incurred during the period 67 Obligations settled during the period (114 ) Revisions in estimated cash flows (1) 228 Accretion 218 AROs at December 31, 2020 (2) $ 5,583 Obligations incurred during the period 31 Obligations settled during the period (165 ) Revisions in estimated cash flows (3) (151 ) Accretion 224 Sale of non-wholly-owned nonregulated solar facilities (49 ) AROs at December 31, 2021 (2) $ 5,473 Virginia Power AROs at December 31, 2019 $ 3,581 Obligations incurred during the period 48 Obligations settled during the period (85 ) Revisions in estimated cash flows ( 4 ) 139 Accretion 137 AROs at December $ 3,820 Obligations incurred during the period 26 Obligations settled during the period (131 ) Revisions in estimated cash flows ( 5 ) 67 Accretion 141 AROs at December $ 3,923 (1) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, asbestos abatement costs associated with certain utility facilities and from the completion of a nuclear decommissioning cost study related to Summer. ( 2 ) Includes $179 million and $198 million reported in other current liabilities at December 31, 2020 and 2021, respectively. (3) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, estimated cash flow projections associated with the recovery of spent nuclear fuel costs for its AROs associated with the decommissioning of Kewaunee and estimated cash flow projections associated with certain gas distribution pipelines. These revisions in 2021 resulted in a charge of $44 million ($35 million after-tax) within other operations and maintenance expense in the Consolidated Statements of Income as well as a $173 million decrease to property, plant and equipment, net. ( 4 ) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities and asbestos abatement costs associated with certain utility facilities. (5) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities. In addition, Virginia Power revised its estimated cash flows for the existing ARO related to future ash pond and landfill closure costs, which resulted in a $113 million ($84 million after-tax) benefit in other operations and maintenance expense in the Consolidated Statements of Income in 2019. Dominion Energy’s AROs at December 31, 2021 and 2020, include $2.0 billion and $1.9 billion, respectively, with $0.9 billion and $0.9 billion recorded by Virginia Power, related to the future decommissioning of their nuclear facilities. The Companies have established trusts dedicated to funding the future decommissioning activities. At December 31, 2021 and 2020, the aggregate fair value of Dominion Energy’s trusts, consisting primarily of equity and debt securities, totaled $8.0 billion and $6.9 billion, respectively. At December 31, 2021 and 2020, the aggregate fair value of Virginia Power’s trusts, consisting primarily of debt and equity securities, totaled $3.7 billion and $3.2 billion, respectively. In addition, AROs at December 31, 2021 and 2020 include $2.9 billion and $2.8 billion, respectively, related to Virginia Power’s future ash pond and landfill closure costs. Regulatory mechanisms, primarily associated with legislation enacted in Virginia in March 2019, provide for recovery of costs to be incurred. See Note 12 for additional information.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases	NOTE 15. LEASES At December 31, 2021 and 2020, the Companies had the following lease assets and liabilities recorded in the Consolidated Balance Sheets: December 31, 2021 December 31, 2020 (millions) Dominion Energy Lease assets: Operating lease assets (1) $ 506 $ 564 Finance lease assets (2) 144 148 Total lease assets $ 650 $ 712 Lease liabilities: Operating lease liabilities (3) $ 44 $ 54 Finance lease liabilities (4) 36 32 Total lease liabilities - current 80 86 Operating lease liabilities (5) 464 516 Finance lease liabilities (6) 112 108 Total lease liabilities - noncurrent 576 624 Total lease liabilities $ 656 $ 710 Virginia Power Operating lease assets (1) $ 256 $ 185 Finance lease assets (2) 71 45 Total lease assets $ 327 $ 230 Lease liabilities: Operating lease liabilities (3) $ 25 $ 28 Finance lease liabilities (4) 13 8 Total lease liabilities - current 38 36 Operating lease liabilities (5) 227 155 Finance lease liabilities (6) 57 36 Total lease liabilities - noncurrent 284 191 Total lease liabilities $ 322 $ 227 (1) Included in other deferred charges and other assets in the Companies’ Consolidated Balance Sheets. (2) Included in property, plant and equipment in the Companies’ Consolidated Balance Sheets, net of $81 million and $18 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2021 and net of $50 million and $9 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2020. (3) Included in other current liabilities in the Companies’ Consolidated Balance Sheets. (4) Included in securities due within one year in the Companies’ Consolidated Balance Sheets. (5) Included in other deferred credits and other liabilities in the Companies’ Consolidated Balance Sheets. (6) Included in other long-term debt in the Companies’ Consolidated Balance Sheets. In addition to the amounts disclosed above, Dominion Energy’s Consolidated Balance Sheets at December 31, 2021 and 2020 includes property, plant and equipment of $1.2 billion and $2.2 billion, respectively, and accumulated depreciation of $106 million and $68 million, respectively, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor. For the years ended December 31, 2021, 2020 and 2019, total lease cost associated with the Companies’ leasing arrangements consisted of the following: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 (millions) Dominion Energy Finance lease cost: Amortization $ 40 $ 33 $ 20 Interest (3 ) — 4 Operating lease cost 66 68 79 Short-term lease cost 32 20 26 Variable lease cost 5 8 5 Total lease cost $ 140 $ 129 $ 134 Virginia Power Finance lease cost: Amortization $ 12 $ 7 $ 3 Interest 1 1 — Operating lease cost $ 30 $ 36 $ 41 Short-term lease cost 19 12 13 Variable lease cost 1 4 2 Total lease cost $ 63 $ 60 $ 59 For the years ended December 31, 2021, 2020 and 2019, cash paid for amounts included in the measurement of the lease liabilities consisted of the following amounts, included in the Companies’ Consolidated Statements of Cash Flows: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 (millions) Dominion Energy Operating cash flows for finance leases $ (3 ) $ — $ 4 Operating cash flows for operating leases 103 96 111 Financing cash flows for finance leases 40 33 20 Virginia Power Operating cash flows for finance leases $ 1 $ 1 $ — Operating cash flows for operating leases 53 52 56 Financing cash flows for finance leases 12 7 3 In addition to the amounts disclosed above, Dominion Energy’s Consolidated Statements of Income for the years ended December 31, 2021, 2020 and 2019, include $168 million, $175 million and $174 million, respectively, of rental revenue, included in operating revenue and $110 million, $102 million and $94 million, respectively, of depreciation expense, included in depreciation, depletion and amortization, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor. At December 31, 2021 and 2020, the weighted average remaining lease term and weighted discount rate for the Companies’ finance and operating leases were as follows: December 31, 2021 December 31, 2020 Dominion Energy Weighted average remaining lease term - finance leases 5 years 5 years Weighted average remaining lease term - operating leases 27 years 26 years Weighted average discount rate - finance leases 2.77 % 3.17 % Weighted average discount rate - operating leases 3.96 % 4.07 % Virginia Power Weighted average remaining lease term - finance leases 6 years 6 years Weighted average remaining lease term - operating leases 25 years 21 years Weighted average discount rate - finance leases 2.27 % 2.51 % Weighted average discount rate - operating leases 4.00 % 4.26 % The Companies’ lease liabilities have the following maturities: Maturity of Lease Liabilities Dominion Energy Virginia Power (millions) Operating Finance Operating Finance 2022 $ 50 $ 32 $ 27 $ 8 2023 41 39 21 14 2024 33 33 17 14 2025 27 18 13 13 2026 24 15 10 10 After 2026 577 22 240 17 Total undiscounted lease payments 752 159 328 76 Present value adjustment (244 ) (11 ) (76 ) (6 ) Present value of lease liabilities $ 508 $ 148 $ 252 $ 70 Corporate Office Leasing Arrangement In December 2019, Dominion Energy signed an agreement with a lessor, as amended in May 2020, to construct and lease a new corporate office property in Richmond, Virginia. The lessor provided equity and had obtained financing commitments from debt investors, totaling $465 million, to fund the estimated project costs. In March 2021, Dominion Energy notified the lessor of its intention to terminate the leasing arrangement effective April 2021. As a result, Dominion Energy recorded a charge of $62 million ($46 million after-tax) in 2021, included in impairments of assets and other charges in its Consolidated Statements of Income, primarily for amounts required to be repaid to the lessor. Offshore Wind Vessel Leasing Arrangement In December 2020, Dominion Energy signed an agreement with a lessor to complete construction of and lease a Jones Act compliant offshore wind installation vessel. This vessel is designed to handle current turbine technologies as well as next generation turbines. The lessor is providing equity and has obtained financing commitments from debt investors, totaling $550 million, to fund the estimated project costs. The project is expected to be completed by the end of 2023. Dominion Energy has been appointed to act as the construction agent for the lessor, during which time Dominion Energy will request cash draws from the lessor and debt investors to fund all project costs, which totaled $293 million as of December 31, 2021. If the project is terminated under certain events of default, Dominion Energy could be required to pay up to 100% of the then funded amount. The initial lease term will commence once construction is substantially complete and the vessel is delivered and will mature in November 2027. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an additional term, subject to the approval of the participants, at current market terms, (ii) purchase the property for an amount equal to the outstanding project costs or, (iii) subject to certain terms and conditions, sell the property on behalf of the lessor to a third party using commercially reasonable efforts to obtain the highest cash purchase price for the property. If the project is sold and the proceeds from the sale are insufficient to repay the investors for the outstanding project costs, Dominion Energy may be required to make a payment to the lessor for the difference between the outstanding project costs and sale proceeds. Dominion Energy is not considered the owner during construction for financial accounting purposes and, therefore, will not reflect the construction activity in its consolidated financial statements. Dominion Energy expects to recognize a right-of-use asset and a corresponding finance lease liability at the commencement of the lease term. Dominion Energy will be considered the owner of the leased property for tax purposes, and as a result, will be entitled to tax deductions for depreciation and interest expense.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2021
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Variable Interest Entities	NOTE 16. VARIABLE INTEREST ENTITIES The primary beneficiary of a VIE is required to consolidate the VIE and to disclose certain information about its significant variable interests in the VIE. The primary beneficiary of a VIE is the entity that has both 1) the power to direct the activities that most significantly impact the entity’s economic performance and 2) the obligation to absorb losses or receive benefits from the entity that could potentially be significant to the VIE. Dominion Energy Through December 2021, Dominion Energy owned the manager and 67% of the membership interest in certain nonregulated solar facilities, as discussed in Note 2. Dominion Energy concluded that these entities were VIEs due to the members lacking the characteristics of a controlling financial interest. In addition, in 2016 Dominion Energy created a wholly owned subsidiary, SBL Holdco, as a holding company of its interest in the VIE nonregulated solar facilities and accordingly SBL Holdco was a VIE. Prior to its disposition in December 2021, Dominion Energy was the primary beneficiary of SBL Holdco and the nonregulated solar facilities, as it had the power to direct the activities that most significantly impact their economic performance as well as the obligation to absorb losses and benefits which could be significant to them. At December 31, 2020, Dominion Energy’s securities due within one year and long-term debt include $ 32 million and $ 239 million, respectively, of debt issued by SBL Holdco net of issuance costs that wa s nonrecourse to Dominion Energy and was secured by SBL Holdco’s interest in certain nonregulated solar facilities. At December 31, 2021, Dominion Energy owns a 50% membership interest in Cove Point, as discussed in Notes 3 and 9. Dominion Energy concluded that Cove Point is a VIE due to the limited partners lacking the characteristics of a controlling financial interest. As a result of the GT&S Transaction, effective November 1, 2020, Dominion Energy is no longer the primary beneficiary of Cove Point as BHE retains the power to direct the activities that most significantly impact Cove Point’s economic performance. Dominion Energy’s maximum exposure to loss is limited to its current and future investment, as well as any obligations under guarantees provided. See Note 23 for more information. At December 31, 2021, Dominion Energy owns a 53% membership interest in Atlantic Coast Pipeline. Dominion Energy concluded that Atlantic Coast Pipeline is a VIE because it has insufficient equity to finance its activities without additional subordinated financial support. Dominion Energy has concluded that it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance, as the power to direct is shared with Duke Energy. Dominion Energy is obligated to provide capital contributions based on its ownership percentage. Dominion Energy’s maximum exposure to loss is limited to any future investment. See Note 9 for more details regarding the nature of this entity. Dominion Energy and Virginia Power The Companies’ nuclear decommissioning trust funds and Dominion Energy’s rabbi trusts hold investments in limited partnerships or similar type entities (see Note 9 for further details). Dominion Energy and Virginia Power concluded that these partnership investments are VIEs due to the limited partners lacking the characteristics of a controlling financial interest. Dominion Energy and Virginia Power have concluded neither is the primary beneficiary as they do not have the power to direct the activities that most significantly impact these VIEs’ economic performance. Dominion Energy and Virginia Power are obligated to provide capital contributions to the partnerships as required by each partnership agreement based on their ownership percentages. Dominion Energy and Virginia Power’s maximum exposure to loss is limited to their current and future investments. Virginia Power Virginia Power had a long-term power and capacity contract with one non-utility generator with an aggregate summer generation capacity of approximately 218 MW. The contract contained certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considered to be variable interests and for which Virginia Power had previously concluded if the generation facility were to be a VIE that it would not be the primary beneficiary. In May 2019, Virginia Power entered into an agreement and paid $135 million to terminate the remaining contract with the non-utility generator. A $135 million ($100 million after-tax) charge was recorded in impairment of assets and other charges in Virginia Power’s Consolidated Statements of Income (reflected in the Corporate and Other segment) during the second quarter of 2019. Virginia Power paid $13 million for electric capacity to non-utility generators and $1 million and million for electric energy to non-utility generators for the year ended December 31, 2019. Virginia Power purchased shared services from DES, an affiliated VIE, of $380 million, $349 million and $387 million for the years ended December 31, 2021, 2020, and 2019, respectively. Virginia Power’s Consolidated Balance Sheets included amounts due to DES of $20 million at December 31, 2021, and $175 million at December 31, 2020, respectively, recorded in payables to affiliates in the Consolidated Balance Sheets. Virginia Power determined that it is not the primary beneficiary of DES as it does not have power to direct the activities that most significantly impact its economic performance as well as the obligation to absorb losses and benefits which could be significant to it. DES provides accounting, legal, finance and certain administrative and technical services to all Dominion Energy subsidiaries, including Virginia Power. Virginia Power has no obligation to absorb more than its allocated share of DES costs.

Short Term Debt and Credit Agre

Short Term Debt and Credit Agreements	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Short-Term Debt and Credit Agreements	NOTE 17. SHORT-TERM DEBT AND CREDIT AGREEMENTS The Companies use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. In addition, Dominion 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 June 2021, Dominion Energy amended its $6.0 billion joint revolving credit facility to provide for a discount in the pricing of certain annual fees and amounts borrowed by Dominion Energy under the facility if Dominion Energy achieves certain annual renewable electric generation and diversity and inclusion objectives. In addition, the amended facility incorporates certain administrative changes with respect to the anticipated transition from LIBOR to an alternative benchmark rate. The key financial covenants are unchanged from the previous facility. Dominion Energy’s short-term financing is supported through its access to the joint revolving credit facility described below. Commercial paper and letters of credit outstanding, as well as capacity available under the credit facility were as follows: Facility Limit Outstanding Commercial Paper (1) Outstanding Letters of Credit Facility Capacity Available (millions) At December 31, 2021 Joint revolving credit facility (2) $ 6,000 $ 1,883 $ 131 $ 3,986 At December 31, 2020 Joint revolving credit facility (2) $ 6,000 $ 627 $ 100 $ 5,273 (1) The weighted-average interest rates of the outstanding commercial paper supported by Dominion Energy’s credit facility was 0.31% and 0.29% at December 31, 2021 and 2020, respectively. (2) This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility 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. DESC and Questar Gas’ short-term financings are supported through access as co-borrowers to the joint revolving credit facility discussed above with the Companies. At December 31, 2021, the sub-limits for DESC and Questar Gas were $500 million and $250 million, respectively. In January 2021, DESC and GENCO applied to FERC for a two-year short-term borrowing authorization. In March 2021, FERC granted DESC authority through March 2023 to issue short-term indebtedness (pursuant to Section 204 of the Federal Power Act) in amounts not to exceed $2.2 billion outstanding with maturity dates of one year or less. In addition, in March 2021, FERC granted GENCO authority through March 2023 to issue short-term indebtedness not to exceed $200 million outstanding with maturity dates of one year or less. In addition to the joint revolving credit facility mentioned above, Dominion Energy also has a credit facility which allows Dominion Energy to issue up to $30 million in letters of credit and matures in June 2022 At December 31, 2021 and 2020, Dominion Energy had $29 million and $30 million, respectively, in letters of credit outstanding under this agreement. In December 2021, in connection with the sale of certain non-wholly owned nonregulated solar facilities, as discussed in Note 10, SBL Holdco terminated $30 million of credit facilities and Dominion Solar Projects III, Inc. terminated $25 million of credit facilities. At December 31, 2020, no amounts were outstanding under either of these facilities. In March 2020, Dominion Energy entered into a $900 million 364-Day Revolving Credit Agreement that bore interest at a variable rate. At December 31, 2020, $225 million was outstanding under the agreement. In March 2021, the agreement reached maturity and Dominion Energy repaid the outstanding borrowed amount in full. In July 2021, Dominion Energy entered into an approximately $1.3 billion term loan credit agreement following the termination of the Q-Pipe Transaction as discussed in Note 3 and borrowed the full amount available thereunder. The term loan was scheduled to mature in December 2021, with the ability to extend maturity at Dominion Energy’s option to June 2022 and bore interest at a variable rate. The proceeds were utilized to repay the deposit received from BHE on the Q-Pipe Transaction. In December 2021, Dominion Energy used the net proceeds from the completion of the sale of the Q-Pipe Group to Southwest Gas to repay the principal outstanding under the term loan plus accrued interest. In December 2021, DECP Holdings entered into a credit facility, which allows it to issue up to $110 million in letters of credit with automatic one-year Dominion Energy has an effective shelf registration statement with the SEC for the sale of up to $3.0 billion of variable denomination floating rate demand notes, called Dominion Energy Reliability Investment SM . The registration limits the principal amount that may be outstanding at any one time to $1.0 billion. The notes are offered on a continuous basis and bear interest at a floating rate per annum determined by the Dominion Energy Reliability Investment Committee, or its designee, on a weekly basis. The notes have no stated maturity date, are non-transferable and may be redeemed in whole or in part by Dominion Energy or at the investor’s option at any time. At December 31, 2021 and December 31, 2020, Dominion Energy’s Consolidated Balance Sheets include $431 million and $268 million, respectively, presented within short-term debt. The proceeds are used for general corporate purposes and to repay debt. Virginia Power Virginia Power’s short-term financing is supported through its access as co-borrower to Dominion Energy’s $6.0 billion joint revolving credit facility, as amended in June 2021 Virginia Power’s share of commercial paper and letters of credit outstanding under the joint revolving credit facility with Dominion Energy, Questar Gas and DESC were as follows: Facility Limit Outstanding Commercial Paper (1) Outstanding Letters of Credit (millions) At December 31, 2021 Joint revolving credit facility (2) $ 6,000 $ 745 $ 40 At December 31, 2020 Joint revolving credit facility (2) $ 6,000 $ 45 $ 12 (1) The weighted-average interest rates of the outstanding commercial paper supported by the credit facility was 0.26% and 0.30% at December 31, 2021 and 2020, respectively. (2) The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Questar Gas and DESC. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At December 31, 2021, the sub-limit for Virginia Power was $1.75 billion. If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion Energy. This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028. The credit facility 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.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Long-Term Debt	NOTE 18. LONG-TERM DEBT At December 31, 2021 Weighted- average Coupon (1) 2021 2020 (millions, except percentages) Virginia Electric and Power Company: Unsecured Senior Notes: 2.30% to 8.875%, due 2022 to 2051 4.07 % $ 13,238 $ 12,689 Tax-Exempt Financings (2) 0.45% to 1.90%, due 2032 to 2041 1.14 % 625 625 Virginia Electric and Power Company total principal $ 13,863 $ 13,314 Securities due within one year 3.45 % (300 ) — Unamortized discount, premium and debt issuances costs, net (110 ) (107 ) Derivative restructuring 446 444 Finance leases 57 36 Virginia Electric and Power Company total long-term debt $ 13,956 $ 13,687 Dominion Energy, Inc.: Supplemental 364-Day credit facility, variable rate, due 2021 $ — $ 225 Sustainability Revolving Credit Agreement, variable rate, due 2024 (3) — — Unsecured Senior Notes: Variable rate, due 2023 0.73 % 1,000 1,000 1.45% to 7.0%, due 2021 to 2049 (4) 3.78 % 11,238 9,938 Unsecured Junior Subordinated Notes: 2.715% to 4.104%, due 2021 and 2024 3.07 % 700 1,950 Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.25% and 5.75%, due 2054 and 2076 (5) 5.75 % 685 1,485 DECP Holdings, Term Loan, variable rate, due 2024 (6) 1.50 % 2,500 — Questar Gas, Unsecured Senior Notes, 2.21% to 7.20%, due 2024 to 2051 3.85 % 1,000 750 East Ohio, Unsecured Senior Notes, 1.30% to 3.00%, due 2025 to 2050 2.25 % 1,800 1,800 PSNC, Senior Debentures and Notes, 3.10% to 7.45%, due 2021 to 2051 4.34 % 800 800 DESC: First Mortgage Bonds, 2.30% to 6.625%, due 2021 to 2065 5.09 % 3,634 3,267 Tax-Exempt Financings (7) Variable rate due 2038 0.14 % 35 35 3.625% and 4.00%, due 2028 and 2033 3.90 % 54 54 GENCO, variable rate due 2038 0.14 % 33 33 Other 3.65 % 1 1 Secured Senior Notes, 4.82%, due 2042 (8) 4.82 % 314 331 Term Loans, variable rates, due 2023 and 2024 (9) — 476 Tax-Exempt Financing, 1.7% due 2033 1.70 % 27 27 Virginia Electric and Power Company total principal (from above) 13,863 13,314 Dominion Energy, Inc. total principal (10) $ 37,694 $ 35,496 Fair value hedge valuation (11) 2 3 Securities due within one year (12) 2.79 % (805 ) (1,905 ) Supplemental 364-Day credit facility borrowings — (225 ) Unamortized discount, premium and debt issuance costs, net (315 ) (293 ) Derivative restructuring 738 773 Finance leases 112 108 Dominion Energy, Inc. total long-term debt $ 37,426 $ 33,957 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2021. (2) These financings relate to certain pollution control equipment at Virginia Power’s generating facilities. (3) This $900 million supplemental credit facility, entered in June 2021, offers a reduced interest rate margin with respect to borrowed amounts allocated to certain environmental sustainability or social investment initiatives. Proceeds of the supplemental credit facility also may be used for general corporate purposes, but such proceeds are not eligible for a reduced interest rate margin. In June 2021 and August 2021, Dominion Energy borrowed $250 million and $650 million respectively. The proceeds from these borrowings were used to support environmental sustainability and social investment initiatives ($250 million) and for general corporate purposes ($650 million). In November 2021 and December 2021, Dominion Energy repaid $650 million and $250 million, respectively, borrowed under this arrangement. ( 4 ) Includes debt assumed by Dominion Energy from the merger of its former CNG subsidiary. (5) In August 2021, Dominion Energy redeemed the remaining principal outstanding of $800 million of its July 2016 hybrids, which would have otherwise matured in 2076. (6) The term loan amortizes over a 17-year period and matures in December 2024 with the potential to be extended to December 2026. The debt is secured by DECP Holdings’ noncontrolling interest in Cove Point. (7 ) Industrial revenue bonds totaling $68 million are secured by letters of credit that expire, subject to renewal, in the fourth quarter of 2022. ( 8 ) Represents debt associated with Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain solar facilities. (9) Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt was nonrecourse to Dominion Energy and was secured by SBL Holdco’s and Dominion Solar Projects III, Inc’s interest in certain solar facilities. In connection with the sales of certain non-wholly owned nonregulated solar facilities discussed in Note 10, the outstanding debt of SBL Holdco was assumed by Terra Nova Renewable Partners and Dominion Energy utilized proceeds from Clearway to repay the outstanding balance of the Dominion Solar Projects III, Inc. term loan. ( 10 ) Excludes amounts classified as held for sale at December 31, 2020. See Note 3. ( 11 ) Represents the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt. ( 12 ) At December 31, 2020, includes $22 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc. Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2021, were as follows: 2022 2023 2024 2025 2026 Thereafter Total (millions, except percentages) Virginia Power Unsecured Senior Notes $ 300 $ 700 $ 350 $ 350 $ 1,150 $ 10,388 $ 13,238 Tax-Exempt Financings — — — — — 625 625 Total $ 300 $ 700 $ 350 $ 350 $ 1,150 $ 11,013 $ 13,863 Weighted-average Coupon 3.45 % 2.75 % 3.45 % 3.10 % 3.08 % 4.16 % Dominion Energy Term Loans $ 151 $ 134 $ 2,215 $ — $ — $ — $ 2,500 First Mortgage Bonds — — — — — 3,634 3,634 Unsecured Senior Notes 650 2,700 690 2,000 2,257 20,779 29,076 Secured Senior Notes 6 17 31 19 20 221 314 Tax-Exempt Financings — — — — — 775 775 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Unsecured Junior Subordinated Notes — — 700 — — — 700 Enhanced Junior Subordinated Notes — — — — — 685 685 Total $ 807 $ 2,851 $ 3,636 $ 2,019 $ 2,277 $ 26,104 $ 37,694 Weighted-average Coupon 2.79 % 1.89 % 2.20 % 3.01 % 2.82 % 4.26 % The Companies’ short-term credit facility and long-term debt agreements contain customary covenants and default provisions. As of December 31, 2021, there were no events of default under these covenants. Senior Note Issuances In January 2022, Virginia Power issued $600 million of 2.40% senior notes and $400 million of 2.95% senior notes that mature in 2032 and 2051, respectively. The proceeds were used for general corporate purposes and/or to repay short-term debt. Enhanced Junior Subordinated Notes In June 2006 and September 2006, Dominion Energy issued $300 million of June 2006 hybrids and $500 million of September 2006 hybrids, respectively. The June 2006 hybrids and the September 2006 hybrids bore interest at the three-month LIBOR plus 2.825%, reset quarterly and at the three-month LIBOR plus 2.3%, reset quarterly, respectively. Dominion Energy executed RCCs in connection with its issuance of the June 2006 hybrids and the September 2006 hybrids. Under the terms of the RCCs, redemptions of the hybrids were subject to certain conditions. In 2019, Dominion Energy purchased and cancelled $12 million and $13 million of its June 2006 hybrids and September 2006 hybrids, respectively. In February 2020, Dominion Energy redeemed the remaining $111 million and $286 million of its June 2006 hybrids and September 2006 hybrids, respectively, both of which would have otherwise matured in 2066. All purchases were conducted in compliance with the applicable RCC, each of which was terminated in February 2020. Expenses related to the early redemption of the hybrids were $10 million reflected within interest and related charges in the Consolidated Statements of Income for the year ended December 31, 2020. In October 2014, Dominion Energy issued $685 million of October 2014 hybrids that will bear interest at 5.75% per year until October 1, 2024. Thereafter, they will bear interest at the three-month LIBOR plus 3.057%, reset quarterly. If the three-month LIBOR is terminated while the October 2014 hybrids are outstanding, they will thereafter bear interest at the last interest rate determined prior to the termination. In July 2016, Dominion Energy issued $800 million of 5.25% July 2016 hybrids. In August 2021, Dominion Energy redeemed the remaining principal outstanding of $800 million of its July 2016 hybrids, which would have otherwise matured in 2076 and were listed on the NYSE under the symbol DRUA. Expenses related to the early redemption of the hybrids were $23 million reflected within interest and related charges in the Consolidated Statements of Income for the year ended December 31, 2021. Dominion Energy may defer interest payments on the hybrids on one or more occasions for up to 10 consecutive years. If the interest payments on the hybrids are deferred, Dominion Energy may not make distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments during the deferral period. Also, during the deferral period, Dominion Energy may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the hybrids. Remarketable Subordinated Notes In June 2019, Dominion Energy successfully remarketed the $700 million 2016 Series A-1 2.0% RSNs due 2021 and $700 million 2016 Series A-2 2.0% RSNs due 2024 pursuant to the terms of the related 2016 Equity Units. In connection with the remarketing, the interest rates on the Series A-1 and Series A-2 notes were reset to 2.715% and 3.071%, respectively, payable on a semi-annual basis, and Dominion Energy ceased to have the ability to redeem the notes at its option or defer interest payments. Dominion Energy did not receive any proceeds from the remarketing. Remarketing proceeds belonged to the investors holding the 2016 Equity Units and were temporarily used to purchase a portfolio of treasury securities. Upon maturity of the portfolio, the proceeds were applied on behalf of the investors on the related stock purchase contract settlement date to pay the purchase price to Dominion Energy for issuance of 18.5 million shares of its common stock in August 2019. Derivative Restructuring In June 2020, Dominion Energy amended a portfolio of interest rate swaps with a notional value of $2.0 billion, extending the mandatory termination dates from 2020 and 2021 to December 2024. As a result of this noncash financing activity with an embedded interest rate swap, In August 2021, Dominion Energy settled certain of the outstanding interest rate swaps which would have otherwise matured in December 2024, resulting in a $39 million reduction in other long-term debt. In August 2020, Virginia Power amended a portfolio of interest rate swaps with a notional value of $900 million, extending the mandatory termination dates from 2020 to December 2023. As a result of this noncash financing activity with an embedded interest rate swap,

Preferred Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Preferred Stock	NOTE 19. PREFERRED STOCK Dominion Energy is authorized to issue up to 20 million shares of preferred stock, DESC is authorized to issue up to 20 million shares of preferred stock. At both December 31, 2021 and 2020, DESC had issued and outstanding 1,000 shares of preferred stock, all of which were held by SCANA and are eliminated in consolidation. Virginia Power is authorized to issue up to 10 million shares of preferred stock, $100 liquidation preference; however, none were issued and outstanding at December 31, 2021 or 2020. 2019 Corporate Units In June 2019, Dominion Energy issued $1.6 billion of 2019 Equity Units, initially in the form of 2019 Series A Corporate Units. The Corporate Units are listed on the NYSE under the symbol DCUE. The net proceeds were used for general corporate purposes and to repay short-term debt, including commercial paper. Each 2019 Series A Corporate Unit consists of a stock purchase contract and a 1/10, or 10%, undivided beneficial ownership interest in one share of Series A Preferred Stock. Beginning in June 2022, the Series A Preferred Stock is convertible at the option of the holder into Dominion Energy common stock under a formula based upon the average closing price of Dominion Energy common stock prior to the conversion date. The Series A Preferred Stock is redeemable in cash by Dominion Energy beginning September 2022 at the liquidation preference. Settlement of any conversion is payable in cash, common stock or a combination thereof, at Dominion Energy’s election. In November 2021, Dominion Energy’s Articles of Incorporation were amended to require that any conversion of its Series A Preferred Stock be settled, at Dominion Energy’s election, either entirely in cash or in cash up to the first $1,000 per share and in shares of Dominion Energy common stock, cash or any combination thereof for any amounts in excess of $1,000 per share. As a result of establishing a minimum amount to be settled in cash if the holders elect to convert the Series A Preferred Stock, $1.6 billion was reclassified from equity to mezzanine equity in 2021. The stock purchase contracts obligate the holders to purchase shares of Dominion Energy common stock in June 2022. The purchase price to be paid under the stock purchase contracts is $100 per Corporate Unit and the number of shares to be purchased will be determined under a formula based upon the average closing price of Dominion Energy common stock near the settlement date. The Series A Preferred Stock was pledged upon issuance as collateral to secure the purchase of common stock under the related stock purchase contracts. Dominion Energy pays cumulative dividends on the Series A Preferred Stock and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion Energy may elect to pay such dividends and/or payments in cash, shares of Dominion Energy common stock or a combination of cash and shares of Dominion Energy common stock. Dominion Energy may defer the contract adjustment payments for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, Dominion Energy may not make any distributions related to its capital stock, including dividends, redemptions, repurchases or liquidation payments. Also, during the deferral period, Dominion Energy may not make any payments on or redeem, repay or repurchase any debt securities that are equal in right of payment with, or subordinated to, the contract adjustment payments or make any payment on any guarantee of a security of a subsidiary if the guarantee ranks equal or junior to the contract adjustment payments. Unless all accumulated and unpaid dividends on the Series A Preferred Stock have been declared and paid, Dominion Energy may not make any distributions on any of its capital stock ranking equal or junior to the Series A Preferred Stock as to dividends or upon liquidation, as applicable, including dividends, redemptions, repurchases or liquidation payments. In such circumstances, Dominion Energy also may not make any contract adjustment payments or other similar types of payments, subject to certain exceptions. Pursuant to the terms of the 2019 Equity Units, Dominion Energy expects to remarket shares of Series A Preferred Stock during the first or second quarter of 2022. Following a successful remarketing, the dividend rate on the preferred stock will be reset and the conversion rate on the preferred stock may increase depending on the closing price of Dominion Energy’s common stock on the date of the remarketing. Dominion Energy will not directly receive any proceeds from the remarketing as the remarketing will be conducted on behalf of investors that, as of the remarketing, continue to hold corporate units or otherwise elect to participate in the remarketing. Proceeds from the remarketing attributable to investors that continue to hold corporate units will be used to purchase a treasury portfolio that upon maturity will be used in June 2022 to pay the purchase price to Dominion Energy for issuance of its common stock under the stock purchase contracts that are a component of such corporate units. Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, the maximum number of shares of common stock Dominion Energy will issue in June 2022 is 21.8 million for consideration of $1.6 billion. Selected information about Dominion Energy’s 2019 Equity Units is presented below: Issuance Date Units Issued Total Net Proceeds (1) Total Preferred Stock (2) Cumulative Dividend Rate Stock Purchase Contract Annual Rate Stock Purchase Contract Liability (3) Stock Purchase Contract Settlement Date (millions except interest rates) 6/14/2019 16 $ 1,582 $ 1,610 1.75 % 5.5 % $ 250 6/1/2022 (1) Issuance costs of $28 million were recorded as a reduction to preferred stock ($14 million) and common stock ($14 million). (2) (3) Payments of $85 million, $83 million and $38 million were made in 2021, 2020 and 2019, respectively. The stock purchase contract liability was $44 million and $129 million at December 31, 2021 and 2020, respectively. Series B Preferred Stock In December 2019, Dominion Energy issued 800,000 shares of Series B Preferred Stock for $791 million, net of $9 million of issuance costs. The preferred stock has a liquidation preference of $1,000 per share and currently pays a 4.65% dividend per share on the liquidation preference. Dividends are paid cumulatively on a semi-annual basis, commencing June 15, 2020. Dominion Energy recorded dividends of $ 37 million ($ 46.50 per share) for the years ended December 31, 202 1 and 20 20 . The dividend rate for the Series B Preferred Stock will be reset every five years beginning on December 15, 2024 to equal the then-current five-year U.S. Treasury rate plus a spread of %. Unless all accumulated and unpaid dividends on the Series B Preferred Stock have been declared and paid, Dominion Energy may not make any distributions on any of its capital stock ranking equal or junior to the Series B Preferred Stock as to dividends or upon liquidation, including through dividends, redemptions, repurchases or otherwise. Dominion Energy may, at its option, redeem the Series B Preferred Stock in whole or in part on December 15, 2024 or on any subsequent fifth anniversary of such date at a price equal to $1,000 per share plus any accumulated and unpaid dividends. Dominion Energy may also, at its option, redeem the Series B Preferred Stock in whole but not in part at a price equal to $1,020 per share plus any accumulated and unpaid dividends at any time within a certain period of time following any change in the criteria ratings agencies use to assign equity credit to securities such as the Series B Preferred Stock that has certain adverse effects on the equity credit actually received by the Series B Preferred Stock. Holders of the Series B Preferred Stock have no voting rights except in the limited circumstances provided for in the terms of the Series B Preferred Stock or as otherwise required by applicable law. The Series B Preferred Stock is not subject to any sinking fund or other obligation of ours to redeem, repurchase or retire the Series B Preferred Stock. The preferred stock contains no conversion rights. Series C Preferred Stock In December 2021, Dominion Energy issued 750,000 shares of Series C Preferred Stock for $742 million, net of $8 million of issuance costs. Also in December 2021, Dominion Energy issued 250,000 shares of Series C Preferred Stock valued at $250 million to the qualified benefit pension plans. See Note 22 for further information regarding activity surrounding pension plan contributions. The preferred stock has a liquidation preference of $1,000 per share and currently pays a 4.35% dividend per share on the liquidation preference. Dividends are paid cumulatively on a semi-annual basis, commencing April 15, 2022. Dominion Energy recorded dividends of $3 million ($2.6583 per share) for the year ended December 31, 2021. The dividend rate for the Series C Preferred Stock will be reset every five years beginning on April 15, 2027 to equal the then-current five-year U.S. Treasury rate plus a spread of 3.195%. Unless all accumulated and unpaid dividends on the Series C Preferred Stock have been declared and paid, Dominion Energy may not make any distributions on any of its capital stock ranking equal or junior to the Series C Preferred Stock as to dividends or upon liquidation, including through dividends, redemptions, repurchases or otherwise. Dominion Energy may, at its option, redeem the Series C Preferred Stock in whole or in part anytime from and including January 15, 2027 through and including April 15, 2027 or during any subsequent fifth anniversary of such period at a price equal to $1,000 per share plus any accumulated and unpaid dividends. Dominion Energy may also, at its option, redeem the Series C Preferred Stock in whole but not in part at a price equal to $1,020 per share plus any accumulated and unpaid dividends at any time within a certain period of time following any change in the criteria ratings agencies use to assign equity credit to securities such as the Series C Preferred Stock that has certain adverse effects on the equity credit actually received by the Series C Preferred Stock. Holders of the Series C Preferred Stock have no voting rights except in the limited circumstances provided for in the terms of the Series C Preferred Stock or as otherwise required by applicable law. The Series C Preferred Stock is not subject to any sinking fund or other obligation of ours to redeem, repurchase or retire the Series C Preferred Stock. The preferred stock contains no conversion rights.

Equity

Equity	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Equity	NOTE 20. EQUITY Common Stock Dominion Energy During 2021, 2020 and 2019, Dominion Energy recorded, net of fees and commissions, $340 million, $481 million and $11.0 billion from the issuance of approximately 4 million, 7 million and 157 million shares of common stock, respectively, for acquisitions, pension plan contributions, settlements of stock purchase contracts and litigation and through various programs including Dominion Energy Direct ® Acquisitions During 2019, Dominion Energy issued 95.6 million shares of common stock in connection with the acquisition of SCANA. At the time of issuance, these common stock shares were valued at $6.8 billion. See Note 3 for further information on the issuance of Dominion Energy common stock in connection with the SCANA Combination. In January 2019, Dominion Energy and Dominion Energy Midstream closed on an agreement and plan of merger pursuant to which Dominion Energy acquired each outstanding common unit representing limited partner interests in Dominion Energy Midstream not already owned by Dominion Energy through the issuance of 22.5 million shares of common stock valued at $1.6 billion. Under the terms of the agreement and plan of merger, each publicly held outstanding common unit representing limited partner interests in Dominion Energy Midstream was converted into the right to receive 0.2492 shares of Dominion Energy common stock. Immediately prior to the closing, each Series A Preferred Unit representing limited partner interests in Dominion Energy Midstream was converted into common units representing limited partner interests in Dominion Energy Midstream in accordance with the terms of Dominion Energy Midstream’s partnership agreement. The merger was accounted for by Dominion Energy following the guidance for a change in a parent company’s ownership interest in a consolidated subsidiary. Because Dominion Energy controls Dominion Energy Midstream both before and after the merger, the changes in Dominion Energy’s ownership interest in Dominion Energy Midstream were accounted for as an equity transaction and no gain or loss was recognized. In connection with the merger, Dominion Energy recognized $40 million of income taxes in equity primarily attributable to establishing additional regulatory liabilities related to excess deferred income taxes and changes in state income taxes. Pension Plan Contribution In December 2019, Dominion Energy contributed 6.1 million shares of its common stock valued at $499 million to the qualified defined benefit pension plans. See Note 22 for further information regarding activity surrounding pension plan contributions. Dominion Energy Direct ® Dominion Energy maintains Dominion Energy Direct ® ® Stock Purchase Contracts In August 2019, Dominion Energy issued 18.5 million shares under the related stock purchase contracts entered into as part of Dominion Energy’s 2016 Equity Units and received proceeds of $1.4 billion. See Note 18 for further information surrounding these stock purchase contracts. Other Issuances In July 2021, Dominion Energy issued 1.4 million shares of its common stock, valued at $104 million, to satisfy DESC’s obligation under a settlement agreement for the FILOT litigation discussed in Note 23. In August 2021, Dominion Energy issued 0.6 million shares of its common stock, valued at $45 million, to satisfy DESC’s obligation for the initial payment under a settlement agreement with the SCDOR discussed in Note 23. In September 2020, Dominion Energy issued 4.1 million shares of its common stock to satisfy its obligation under a settlement agreement for the Santee Cooper Ratepayer Case discussed in Note 23. These shares were immediately repurchased as discussed below. At-the-Market Program In February 2018, Dominion Energy entered into sales agency agreements to effect sales under an at-the-market program. In the fourth quarter of 2018, Dominion Energy issued 2.7 million shares and received cash proceeds of $197 million, net of fees and commissions paid of $2 million. In the first quarter of 2019, Dominion Energy issued 2.1 million shares and received cash proceeds of $154 million, net of fees and commissions paid of $2 million. In the fourth quarter of 2019, Dominion Energy issued 7.8 million shares and received cash proceeds of $639 million, net of fees and commissions paid of $6 million. Following these issuances, Dominion Energy had no remaining capacity under this program. In March 2020, Dominion Energy entered into sales agency agreements to effect sales under a $500 million at-the-market common stock program. Dominion Energy did not issue any shares under this program which expired in June 2020. In August 2020, Dominion Energy entered into sales agency agreements to effect sales under a new at-the-market program. Under the sales agency agreements, Dominion Energy may, from time to time, offer and sell shares of its common stock through the sales agents or enter into one or more forward sale agreements with respect to shares of its common stock. Sales by Dominion Energy through the sales agents or by forward sellers pursuant to a forward sale agreement cannot exceed $ 1.0 billion in the aggregate. In November 2021, Dominion Energy entered forward sale agreements for approximately 1.1 million shares of its common stock to be settled by November 2022 at an initial forward price of $ 74.66 per share. 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. A net share settlement could require us to deliver a number of shares significantly lower than would be issued in connection with a full physical settlement. Repurchase of Common Stock Dominion Energy did not repurchase any shares in 2021 or 2019, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock, which do not count against its stock repurchase authorization. During 2020, Dominion Energy repurchased 38.9 million shares of Dominion Energy common stock for $3.1 billion through an open market agreement, a private transaction and accelerated share repurchase agreements as discussed below. In July 2020, in contemplation of Dominion Energy entering the July 2020 agreement to sell substantially all of its gas transmission and storage operations to BHE, the Board of Directors authorized the repurchase of up to $3.0 billion of Dominion Energy’s common stock and rescinded its prior repurchase authorization approved in February 2005 and modified in June 2007 ominion Energy completed repurchases under this authorization in December 2020. In August 2020, Dominion Energy began repurchasing shares under an open market agreement with a financial institution. During the third quarter of 2020, Dominion Energy repurchased 7.2 million shares of Dominion Energy common stock for $562 million. During the fourth quarter of 2020, Dominion Energy repurchased 3.7 million shares of Dominion Energy common stock for $295 million. In September 2020, Dominion Energy repurchased 4.1 million shares of Dominion Energy common stock in a private transaction for $323 million. In September 2020, Dominion Energy entered into two prepaid accelerated share repurchase agreements with separate financial institutions as counterparties. Dominion Energy made payments totaling $1.5 billion to the counterparties in exchange for an aggregate of 17.2 million shares of Dominion Energy common stock, which represented approximately 90% of $1.5 billion worth of Dominion Energy shares based on the closing price of such shares on the date the agreements were executed. In November 2020, Dominion Energy received an additional 1.4 million shares upon completion of the respective purchase periods under the terms of the agreements. The number of additional shares delivered under each agreement was based on the average of the daily volume-weighted average stock prices of Dominion Energy’s common stock during the term of the applicable purchase period, less a discount. As a result, Dominion Energy recorded a reduction to common stock of $1.5 billion. Virginia Power In 2021, 2020 and 2019, Virginia Power did not issue any shares of its common stock to Dominion Energy. Noncontrolling Interests GT&S Transaction Closing In November 2020, as part of the GT&S Transaction, Dominion Energy sold a 25% controlling interest in Cove Point to BHE resulting in Dominion Energy’s remaining 50% noncontrolling interest accounted for as an equity method investment prospectively. As a result, the $ 1.4 billion of noncontrolling interest related to the 25 % interest in Cove Point held by Brookfield was reversed. See Notes 3 and 9 for further information on the GT&S Transaction and Dominion Energy’s equity method investment in Cove Point. Sale of Interest in Cove Point In December 2019, Dominion Energy completed the sale of its 25% noncontrolling limited partnership interest in Cove Point to Brookfield in exchange for cash consideration of $2.1 billion, subject to working capital adjustments. See Note 3 for further information on the sale of this interest. Non-Wholly-Owned Nonregulated Solar Facilities In December 2021, Dominion Energy completed the sale of SBL Holdco, which held Dominion Energy’s 67% controlling interest in certain nonregulated solar projects, and the sale of its 50% controlling interest in Four Brothers and Three Cedars. As a result of these sales, all balances recorded as noncontrolling interests associated with these entities were written off. See Note 10 for more information . Accumulated Other Comprehensive Income (Loss) Dominion Energy The following table presents Dominion Energy’s changes in AOCI (net of tax) and reclassifications out of AOCI by component: Commodity Interest Rate Foreign Currency Total Derivative-Hedging Activities (1) Investment Securities (2) Pension and other postretirement benefit costs (3) Equity Method Investees (4) Total (millions) Year Ended December 31, 2021 Beginning balance $ (1 ) $ (418 ) $ — $ (419 ) $ 62 $ (1,359 ) $ (1 ) $ (1,717 ) Other comprehensive income before reclassifications: gains (losses) — 15 — 15 (7 ) 144 (3 ) 149 Amounts reclassified from AOCI: (gains) losses Purchased gas 1 — — 1 — — — 1 Interest and related charges — 60 — 60 — — — 60 Other income — — — — (23 ) 111 — 88 Total 1 60 — 61 (23 ) 111 — 149 Income tax expense — (15 ) — (15 ) 5 (29 ) — (39 ) Total, net of tax 1 45 — 46 (18 ) 82 — 110 Net current period other comprehensive income (loss) 1 60 — 61 (25 ) 226 (3 ) 259 Ending balance $ — $ (358 ) $ — $ (358 ) $ 37 $ (1,133 ) $ (4 ) $ (1,458 ) Year Ended December 31, 2020 Beginning balance $ 16 $ (426 ) $ 3 $ (407 ) $ 37 $ (1,421 ) $ (2 ) $ (1,793 ) Other comprehensive income before reclassifications: gains (losses) — (231 ) (8 ) (239 ) 43 25 1 (170 ) Amounts reclassified from AOCI: (gains) losses Operating revenue (25 ) — — (25 ) — — — (25 ) Purchased gas 4 — — 4 — — — 4 Discontinued operations (2 ) 236 6 240 — — — 240 Interest and related charges — 83 — 83 — — — 83 Other income — — — — (24 ) 50 — 26 Total (23 ) 319 6 302 (24 ) 50 — 328 Income tax expense 6 (80 ) (1 ) (75 ) 6 (13 ) — (82 ) Total, net of tax (17 ) 239 5 227 (18 ) 37 — 246 Net current period other comprehensive income (loss) (17 ) 8 (3 ) (12 ) 25 62 1 76 Ending balance $ (1 ) $ (418 ) $ — $ (419 ) $ 62 $ (1,359 ) $ (1 ) $ (1,717 ) (1) Net of $119 million (2) Net of $(10) million and $(21) million tax at December 31, 2021 and 2020, respectively. (3) Net of $396 million and $478 million tax at December 31, 2021 and 2020, respectively. (4) Net of $1 million and $— million tax at December 31, 2021 and 2020, respectively. Virginia Power The following table presents Virginia Power’s changes in AOCI (net of tax) and reclassification out of AOCI by component: Interest Rate Total Derivative-Hedging Activities (1) Investment Securities (2) Total (millions) Year Ended December 31, 2021 Beginning balance $ (60 ) $ (60 ) $ 8 $ (52 ) Other comprehensive income before reclassifications: gains (losses) 13 13 (2 ) 11 Amounts reclassified from AOCI: (gains) losses Interest and related charges 3 3 — 3 Other income — — (3 ) (3 ) Total 3 3 (3 ) — Income tax expense (1 ) (1 ) 1 — Total, net of tax 2 2 (2 ) — Net current period other comprehensive income (loss) 15 15 (4 ) 11 Ending balance $ (45 ) $ (45 ) $ 4 $ (41 ) Year Ended December 31, 2020 Beginning balance $ (34 ) $ (34 ) $ 5 $ (29 ) Other comprehensive income before reclassifications: gains (losses) (28 ) (28 ) 6 (22 ) Amounts reclassified from AOCI: (gains) losses Interest and related charges 2 2 — 2 Other income — — (4 ) (4 ) Total 2 2 (4 ) (2 ) Income tax expense — — 1 1 Total, net of tax 2 2 (3 ) (1 ) Net current period other comprehensive income (loss) (26 ) (26 ) 3 (23 ) Ending balance $ (60 ) $ (60 ) $ 8 $ (52 ) (1) Net of $16 million and (2) Net of $(2) million and $(3) million tax at December 31, 2021 and 2020, respectively. Stock-Based Awards The 2014 Incentive Compensation Plan permits stock-based awards that include restricted stock, performance grants, goal-based stock, stock options and stock appreciation rights. The Non-Employee Directors Compensation Plan permits grants of restricted stock and stock options. Under provisions of these plans, employees and non-employee directors may be granted options to purchase common stock at a price not less than its fair market value at the date of grant with a maximum term of eight years. Option terms are set at the discretion of the Compensation and Talent Development Committee of the Board of Directors or the Board of Directors itself, as provided under each plan. No options are outstanding under either plan. At December 31, 2021, approximately 19 million shares were available for future grants under these plans. Goal-based stock awards are granted in lieu of cash-based performance grants to certain officers who have not achieved a certain targeted level of share ownership. As of December 31, 2021, unrecognized compensation cost related to nonvested goal-based stock awards was immaterial. Dominion Energy measures and recognizes compensation expense relating to share-based payment transactions over the vesting period based on the fair value of the equity or liability instruments issued. Dominion Energy’s results for the years ended December 31, 2021, 2020 and 2019 include $42 million, $64 million and $46 million, Restricted Stock Restricted stock grants are made to officers under Dominion Energy’s LTIP and may also be granted to certain key non-officer employees. The fair value of Dominion Energy’s restricted stock awards is equal to the closing price of Dominion Energy’s stock on the date of grant. New shares are issued for restricted stock awards on the date of grant and generally vest over a three-year Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2018 1,208 $ 73.03 Granted 614 76.49 Vested (324 ) 71.75 Cancelled and forfeited (96 ) 77.16 Nonvested at December 31, 2019 1,402 $ 74.77 Granted 531 81.74 Vested (424 ) 74.39 Cancelled and forfeited (99 ) 81.59 Nonvested at December 31, 2020 1,410 $ 77.41 Granted 518 71.78 Vested (505 ) 73.54 Cancelled and forfeited (113 ) 75.57 Nonvested at December 31, 2021 1,310 $ 76.65 As of December 31, 2021, unrecognized compensation cost related to nonvested restricted stock awards totaled $55 million and is expected to be recognized over a weighted-average period of 2.0 years. The fair value of restricted stock awards that vested was $37 million, $35 million and $23 million in 2021, 2020 and 2019, respectively. Employees may elect to have shares of restricted stock withheld upon vesting to satisfy tax withholding obligations. The number of shares withheld will vary for each employee depending on the vesting date fair market value of Dominion Energy stock and the applicable federal, state and local tax withholding rates. Cash-Based Performance Grants Cash-based performance grants are made to Dominion Energy’s officers under Dominion Energy’s LTIP. The actual payout of cash-based performance grants will vary between zero and 200% of the targeted amount based on the level of performance metrics achieved. In February 2019, a cash-based performance grant was made to officers. Payout of the performance grant occurred in January 2022 based on the achievement of two performance metrics during 2019, 2020 and 2021: TSR relative to that of companies that are members of Dominion Energy’s compensation peer group and ROIC with an additional payout based on Dominion Energy’s price-earnings ratio relative to that of the members of Dominion Energy’s peer compensation group. The total payout under the grant was $5.7 million, all of which was accrued at December 31, 2021. In February 2020, a cash-based performance grant was made to officers. Payout of the performance grant is expected to occur by March 15, 2023 based on the achievement of two performance metrics during 2020, 2021 and 2022: TSR relative to that of companies that are members of Dominion Energy’s compensation peer group and ROIC. There are additional opportunities to earn a portion of the award based on Dominion Energy’s absolute TSR or relative price-earnings ratio performance. At December 31, 2021, the targeted amount of the three-year grant was $10 million and a liability of $6 million had been accrued for this award. In February 2021, a cash-based performance grant was made to officers. Payout of the performance grant is expected to occur by March 15, 2024 based on the achievement of two performance metrics during 2021, 2022 and 2023: TSR relative to that of companies that are members of Dominion Energy’s compensation peer group and ROIC. There is an additional opportunity to earn a portion of the award based on Dominion Energy’s relative price-earnings ratio performance. At December 31, 2021, the targeted amount of the three-year grant was $13 million and a liability of $4 million had been accrued for this award.

Dividend Restrictions

Dividend Restrictions	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Dividend Restrictions	NOTE 21. DIVIDEND RESTRICTIONS The Virginia Commission may prohibit any public service company, including Virginia Power, from declaring or paying a dividend to an affiliate if found to be inconsistent with the public interest. At December 31, 2021, the Virginia Commission had not restricted the payment of dividends by Virginia Power. The North Carolina Commission, in its order approving the SCANA Combination, limited cumulative dividends payable to Dominion Energy by Virginia Power and PSNC to (i) the amount of retained earnings the day prior to closing of the SCANA Combination plus (ii) any future earnings recorded by Virginia Power and PSNC after such closing. In addition, notice to the North Carolina Commission is required if payment of dividends causes the equity component of Virginia Power and PSNC’s capital structure to fall below 45%. The Ohio and Utah Commissions may prohibit any public service company, including East Ohio and Questar Gas, from declaring or paying a dividend to an affiliate if found to be detrimental to the public interest. At December 31, 2021, neither the Ohio Commission nor the Utah Commission had restricted the payment of dividends by East Ohio or Questar Gas, respectively. There is no specific restriction from the South Carolina Commission on the payment of dividends paid by DESC. Pursuant to the SCANA Merger Approval Order, the amount of any DESC dividends paid must be reasonable and consistent with the long-term payout ratio of the electric utility industry and gas distribution industry. At December 31, 2021, DESC’s retained earnings exceed the balance established by the Federal Power Act as a reserve on earnings attributable to hydroelectric generation plants. As a result, DESC is permitted to pay dividends without additional regulatory approval provided that such amounts would not bring the retained earnings balance below the threshold. See Notes 18 and 19 for a description of potential restrictions on common stock dividend payments by Dominion Energy in connection with the deferral of interest payments on the enhanced junior subordinated notes, the deferral of contract adjustment payments on the 2019 Equity Units or a failure to pay dividends on the Series A Preferred Stock, Series B Preferred Stock or Series C Preferred Stock.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2021
Compensation And Retirement Disclosure [Abstract]
Employee Benefit Plans	NOTE 22. EMPLOYEE BENEFIT PLANS Dominion Energy—Defined Benefit Plans Dominion Energy provides certain retirement benefits to eligible active employees, retirees and qualifying dependents. Under the terms of its benefit plans, Dominion Energy reserves the right to change, modify or terminate the plans. From time to time in the past, benefits have changed, and some of these changes have reduced benefits. Dominion Energy maintains qualified noncontributory defined benefit pension plans covering virtually all employees who commenced employment prior to July 2021. Retirement benefits are based primarily on years of service, age and the employee’s compensation. Dominion Energy’s funding policy is to contribute annually an amount that is in accordance with the provisions of ERISA. The pension programs also provide benefits to certain retired executives under company-sponsored nonqualified employee benefit plans. The nonqualified plans are funded through contributions to grantor trusts. Dominion Energy also provides retiree healthcare and life insurance benefits with annual employee premiums based on several factors such as age, retirement date and years of service. Pension and other postretirement benefit costs are affected by employee demographics (including age, compensation levels and years of service), the level of contributions made to the plans and earnings on plan assets. These costs may also be affected by changes in key assumptions, including expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates, mortality rates and the rate of compensation increases. Dominion Energy uses December 31 as the measurement date for all of its employee benefit plans. Dominion Energy uses the market-related value of pension plan assets to determine the expected return on plan assets, a component of net periodic pension cost, for all pension plans. The market-related value recognizes changes in fair value on a straight-line basis over a four-year period, which reduces year-to-year volatility. Changes in fair value are measured as the difference between the expected and actual plan asset returns, including dividends, interest and realized and unrealized investment gains and losses. Since the market-related value recognizes changes in fair value over a four-year period, the future market-related value of pension plan assets will be impacted as previously unrecognized changes in fair value are recognized. Dominion Energy’s pension and other postretirement benefit plans hold investments in trusts to fund employee benefit payments. Dominion Energy’s pension and other postretirement plan assets experienced aggregate actual returns (losses) of $1.5 billion and $1.9 billion in 2021 and 2020, respectively, versus expected returns of $1.0 billion and $933 million, respectively. Differences between actual and expected returns on plan assets are accumulated and amortized during future periods. As such, any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans. In the fourth quarter of 2021, Dominion Energy recognized the effects of a curtailment for certain pension plans resulting from an option that will provide certain active employees a one-time choice to transition to an enhanced defined contribution plan in lieu of accruing pension benefits for future services. The curtailment resulted in a decrease in the pension benefit obligation of $26 million and an increase to net periodic pension cost of $2 million. The effects of the curtailment are included in the measurement of Dominion Energy’s pension plans as of December 31, 2021. In the third quarter of 2020, Dominion Energy remeasured certain pension plans due to a curtailment resulting from entering an agreement to sell substantially all of its gas transmission and storage operations to BHE. The remeasurement resulted in an increase in the pension benefit obligation of $497 million and a decrease in the fair value of the pension plan assets of $87 million. The impact of the remeasurement on net periodic pension benefit cost (credit) was recognized prospectively from the remeasurement date. The remeasurement increased the net periodic benefit credit by approximately $4 million for the year ending December 31, 2020, excluding the impacts of curtailments. The discount rate used for the remeasurement was 3.11% - 3.16% with all other assumptions used for the remeasurement consistent with the measurement as of December 31, 2019. In the fourth quarter of 2020, Dominion Energy remeasured certain other postretirement benefit plans due to a curtailment and settlement resulting from Dominion Energy completing the GT&S Transaction. The remeasurement resulted in an increase in the accumulated postretirement benefit obligation of $16 million and a decrease in the fair value of the other postretirement benefit plan assets of $25 million. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The discount rate used for the remeasurement was 3.07% - 3.11%. The initial healthcare cost trend rate used for the remeasurement was 6.25% and decreased to 5.00% by 2025-2026. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2019. Voluntary Retirement Program In March 2019, the Companies announced a voluntary retirement program to employees that meet certain age and service requirements. In 2019, upon the determinations made concerning the number of employees that elected to participate in the program, Dominion Energy recorded a charge of $427 million ($319 million after-tax) included within other operations and maintenance expense ($251 million), other taxes ($21 million), other income ($111 million) and discontinued operations ($44 million) and Virginia Power recorded a charge of $198 million ($146 million after-tax) included within other operations and maintenance expense ($190 million) and other taxes ($8 million) in their respective Consolidated Statements of Income. In the second quarter of 2019, Dominion Energy remeasured its pension and other postretirement benefit plans as a result of the voluntary retirement program. The remeasurement resulted in an increase in the pension benefit obligation of $484 million and an increase in the fair value of the pension plan assets of $671 million. In addition, the remeasurement resulted in an increase in the accumulated postretirement benefit obligation of $101 million and an increase in the fair value of the other postretirement benefit plan assets of $156 million. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The discount — — In the third quarter of 2019, Dominion Energy remeasured a pension plan as a result of a settlement from the voluntary retirement program at SCANA. The settlement and related remeasurement resulted in an increase in the pension benefit obligation of $37 million and an increase in the fair value of the pension plan assets of $51 million for Dominion Energy. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The discount rate used for the remeasurement was 3.57%. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2018. Funded Status The following table summarizes the changes in pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans’ funded status for Dominion Energy: Pension Benefits Other Postretirement Benefits Year Ended December 31, 2021 2020 2021 2020 (millions, except percentages) Dominion Energy Changes in benefit obligation: Benefit obligation at beginning of year $ 11,363 $ 10,446 $ 1,746 $ 1,769 Service cost 170 173 25 28 Interest cost 317 351 46 58 Benefits paid (488 ) (461 ) (105 ) (120 ) Actuarial (gains) losses during the year (413 ) 992 (161 ) 33 Plan amendments — — (14 ) (6 ) Settlements and curtailments (1) (59 ) (138 ) — (16 ) Benefit obligation at end of year $ 10,890 $ 11,363 $ 1,537 $ 1,746 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 10,979 $ 9,631 $ 2,100 $ 1,880 Actual return (loss) on plan assets 1,202 1,602 294 300 Employer contributions 284 278 — 13 Benefits paid (488 ) (461 ) (71 ) (93 ) Settlements (2) (32 ) (71 ) — — Fair value of plan assets at end of year $ 11,945 $ 10,979 $ 2,323 $ 2,100 Funded status at end of year $ 1,055 $ (384 ) $ 786 $ 354 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 1,246 $ 1,054 $ 1,064 $ 650 Other current liabilities (12 ) (14 ) (15 ) (15 ) Noncurrent pension and other postretirement benefit liabilities (179 ) (1,424 ) (263 ) (281 ) Net amount recognized $ 1,055 $ (384 ) $ 786 $ 354 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 3.06%-3.19% 2.73%–2.95% 3.04%-3.11% 2.69%–2.80% Weighted average rate of increase for compensation 4.51% 4.53% n/a n/a Crediting interest rate for cash balance and similar plans 1.81%-1.94% 1.93% - 2.15% n/a n/a (1) 2021 amounts include curtailments and settlements recognized primarily as a result of the employee choice program and settlements of nonqualified pension obligations. 2020 amounts include curtailment and settlements recognized as a result of the GT&S Transaction as well as settlements of qualified and nonqualified pension obligations. (2) 2021 amounts relate to settlements of nonqualified pension obligations and 2020 amounts relate primarily to settlements of qualified and nonqualified pension obligations. Actuarial gains recognized during 2021 in Dominion Energy’s pension benefit obligations were $413 million primarily driven by an increase in discount rates. Actuarial losses recognized during 2020 in Dominion Energy’s pension benefit obligations include a $1.0 billion loss resulting primarily from a decrease in discount rate. Actuarial gains recognized during 2021 in Dominion Energy’s other postretirement benefit obligations were $161 million resulting from an increase in discount rates, better than expected per capita claims experience and changes in demographic and economic assumptions based on an experience study completed in 2021. Actuarial losses recognized during 2020 in Dominion Energy’s other postretirement benefit obligations include a $149 million loss resulting from a decrease in discount rates and were partially offset by an $85 million actuarial gain as a result of a completed experience study in one of Dominion Energy’s other postretirement plans and the impact of an update to healthcare claims assumptions. The ABO for all of Dominion Energy’s defined benefit pension plans was $10.2 billion and $10.6 billion at December 31, 2021 and 2020, respectively. Under its funding policies, Dominion Energy evaluates plan funding requirements annually, usually in the fourth quarter after receiving updated plan information from its actuary. Based on the funded status of each plan and other factors, Dominion Energy determines the amount of contributions for the current year, if any, at that time. In December 2021, Dominion Energy issued 250,000 shares of its Series C Preferred Stock to its qualified defined benefit pension plans, valued at $250 million. In December 2020, Dominion Energy contributed $250 million to its qualified defined benefit pension plans. During 2019, Dominion Energy made $520 million of contributions to its qualified defined benefit pension plans, including 6.1 million shares of its common stock valued at $499 million. The shares of common and preferred stock were contributed though private placements exempt from registration requirements, with an independent fiduciary and investment manager to a separate account within the qualified defined benefit pension plans. Dominion Energy also entered into a registration rights agreement with the independent fiduciary and investment manager pursuant to which Dominion Energy agreed to provide registration rights on customary terms with respect to the shares of common and preferred stock. Dominion Energy is not required to make any contributions to its qualified defined benefit pension plans in 202 2 . Dominion Energy considers voluntary contributions from time to time, either in the form of cash or equity securities. Certain of Dominion Energy’s subsidiaries fund other postretirement benefit costs through VEBAs. Dominion Energy’s remaining subsidiaries do not prefund other postretirement benefit costs but instead pay claims as presented. Dominion Energy did not make any contributions to VEBAs associated with its other postretirement plans in 2021 and 2020. Dominion Energy’s contributions to VEBAs, all of which pertained to employees of operations sold to BHE, totaled $12 million for 2019. The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets for Dominion Energy: Pension Benefits Other Postretirement Benefits As of December 31, 2021 2020 2021 2020 (millions) Dominion Energy Benefit obligation $ 9,420 $ 10,697 $ 261 $ 305 Fair value of plan assets 9,229 9,259 7 9 The following table provides information on the ABO and fair value of plan assets for Dominion Energy’s pension plans with an ABO in excess of plan assets: As of December 31, 2021 2020 (millions) Accumulated benefit obligation $ 127 $ 9,970 Fair value of plan assets 53 9,259 The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion Energy’s plans: Estimated Future Benefit Payments Pension Benefits Other Postretirement Benefits (millions) Dominion Energy 2022 $ 513 $ 101 2023 516 100 2024 529 99 2025 541 97 2026 548 96 2027-2031 2,833 450 Plan Assets Dominion Energy’s overall objective for investing its pension and other postretirement plan assets is to achieve appropriate long-term rates of return commensurate with prudent levels of risk. To minimize risk, funds are broadly diversified among asset classes, investment strategies and investment advisors. The strategic target asset allocations for substantially all of Dominion Energy’s pension funds are 27% U.S. equity, 18% non-U.S. equity, 32% fixed income, 3% real estate and 20% other alternative investments. U.S. equity includes investments in large-cap, mid-cap and small-cap companies located in the U.S. Non-U.S. equity includes investments in large-cap and small-cap companies located outside of the U.S. including both developed and emerging markets. Fixed income includes corporate debt instruments of companies from diversified industries and U.S. Treasuries. The U.S. equity, non-U.S. equity and fixed income investments are in individual securities as well as mutual funds. Real estate includes equity real estate investment trusts and investments in partnerships. Other alternative investments include partnership investments in private equity, debt and hedge funds that follow several different strategies. Dominion Energy also utilizes common/collective trust funds as an investment vehicle for its defined benefit plans. A common/collective trust fund is a pooled fund operated by a bank or trust company for investment of the assets of various organizations and individuals in a well-diversified portfolio. Common/collective trust funds are funds of grouped assets that follow various investment strategies. Strategic investment policies are established for Dominion Energy’s prefunded benefit plans based upon periodic asset/liability studies. Factors considered in setting the investment policy include employee demographics, liability growth rates, future discount rates, the funded status of the plans and the expected long-term rate of return on plan assets. Deviations from the plans’ strategic allocation are a function of Dominion Energy’s assessments regarding short-term risk and reward opportunities in the capital markets and/or short-term market movements which result in the plans’ actual asset allocations varying from the strategic target asset allocations. Through periodic rebalancing, actual allocations are brought back in line with the target. Future asset/liability studies will focus on strategies to further reduce pension and other postretirement plan risk, while still achieving attractive levels of returns. Financial derivatives may be used to obtain or manage market exposures and to hedge assets and liabilities. For fair value measurement policies and procedures related to pension and other postretirement benefit plan assets, see Note 6. The fair values of Dominion Energy’s pension plan assets by asset category are as follows: At December 31, 2021 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 25 $ 5 $ — $ 30 $ 20 $ 1 $ — $ 21 Common and preferred stocks: U.S. (1) 2,592 244 — 2,836 2,405 — — 2,405 International 1,773 19 — 1,792 1,727 — — 1,727 Insurance contracts — 279 — 279 — 409 — 409 Corporate debt instruments 81 1,439 — 1,520 32 1,385 — 1,417 Government securities 39 914 — 953 30 772 — 802 Total recorded at fair value $ 4,510 $ 2,900 $ — $ 7,410 $ 4,214 $ 2,567 $ — $ 6,781 Assets recorded at NAV (2) Common/collective trust funds 3,010 2,905 Alternative investments: Real estate funds 116 108 Private equity funds 1,233 856 Debt funds 162 168 Hedge funds 14 13 Total recorded at NAV $ 4,535 $ 4,050 Total investments (3) $ 11,945 $ 10,831 (1) Includes $258 million of Dominion Energy preferred stock and no Dominion Energy common stock at December 31, 2021 and $365 million of Dominion Energy common stock at December 31, 2020. (2) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient are not required to be categorized in the fair value hierarchy. (3) Excludes net assets related to pending sales of securities of $35 million, net accrued income of $27 The fair values of Dominion Energy’s other postretirement plan assets by asset category are as follows: At December 31, 2021 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 3 $ 1 $ — $ 4 $ — $ 2 $ — $ 2 Common and preferred stocks: U.S. 898 14 — 912 817 — — 817 International 256 1 — 257 240 — — 240 Insurance contracts — 16 — 16 — 23 — 23 Corporate debt instruments 5 61 — 66 2 60 — 62 Government securities 2 47 — 49 2 42 — 44 Total recorded at fair value $ 1,164 $ 140 $ — $ 1,304 $ 1,061 $ 127 $ — $ 1,188 Assets recorded at NAV (1) Common/collective trust funds 840 765 Alternative investments: Real estate funds 13 10 Private equity funds 152 117 Debt funds 9 10 Hedge funds 1 1 Total recorded at NAV $ 1,015 $ 903 Total investments (2) $ 2,319 $ 2,091 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $5 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2021. Excludes net assets related to pending sales of securities of $10 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2020. The plan assets investments are determined based on the fair values of the investments and the underlying investments, which have been determined as follows: • Cash and Cash Equivalents —Investments are held primarily in short-term notes and treasury bills, which are valued at cost plus accrued interest. • Common and Preferred Stocks —Investments are valued at the closing price reported on the active market on which the individual securities are traded. • Insurance Contracts —Investments in Group Annuity Contracts with John Hancock were entered into after 1992 and are stated at fair value based on the fair value of the underlying securities as provided by the managers and include investments in U.S. government securities, corporate debt instruments and state and municipal debt securities. • Corporate Debt Instruments —Investments are valued using pricing models maximizing the use of observable inputs for similar securities. This includes basing value on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar instruments, the instrument is valued under a discounted cash flows approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks or a broker quote, if available. • Government Securities —Investments are valued using pricing models maximizing the use of observable inputs for similar securities. • Common/Collective Trust Funds —Common/collective trust funds invest in debt and equity securities and other instruments with characteristics similar to those of the funds’ benchmarks. The primary objectives of the funds are to seek investment returns that approximate the overall performance of their benchmark indexes. These benchmarks are major equity indices, fixed income indices and money market indices that focus on growth, income and liquidity strategies, as applicable. Investments in common/collective trust funds are stated at the NAV as determined by the issuer of the common/collective trust funds and are based on the fair value of the underlying investments held by the fund less its liabilities. The NAV is used as a practical expedient to estimate fair value. The common/collective trust funds do not have any unfunded commitments, and do not have any applicable liquidation periods or defined terms/periods to be held. The majority of the common/collective trust funds have limited withdrawal or redemption rights during the term of the investment. • Alternative Investments —Investments in real estate funds, private equity funds, debt funds and hedge funds are stated at fair value based on the NAV of the plan’s proportionate share of the partnership, joint venture or other alternative investment’s fair value as determined by reference to audited financial statements or NAV statements provided by the investment manager. The NAV, which is used as a practical expedient to estimate fair value, is adjusted for contributions and distributions occurring between the investment manager’s and Dominion Energy’s measurement date. These valuations also involve assumptions and methods that are reviewed, evaluated, and adjusted, if necessary, by Dominion Energy. Net Periodic Benefit (Credit) Cost The service cost component of net periodic benefit (credit) cost is reflected in other operations and maintenance expense in Dominion Energy’s Consolidated Statements of Income , Pension Benefits Other Postretirement Benefits Year Ended December 31, 2021 2020 2019 2021 2020 2019 (millions, except percentages) Dominion Energy Service cost $ 170 $ 173 $ 162 $ 25 $ 28 $ 26 Interest cost 317 351 394 46 58 68 Expected return on plan assets (834 ) (777 ) (708 ) (173 ) (156 ) (140 ) Amortization of prior service (credit) cost — 1 1 (42 ) (49 ) (52 ) Amortization of net actuarial loss 193 206 172 4 6 10 Settlements, curtailments and special termination benefits 10 14 72 — (59 ) 42 Net periodic benefit (credit) cost $ (144 ) $ (32 ) $ 93 $ (140 ) $ (172 ) $ (46 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ (782 ) $ 166 $ 16 $ (282 ) $ (110 ) $ (98 ) Prior service (credit) cost — — — (13 ) (6 ) 2 Settlements and curtailments (36 ) (81 ) 6 — 59 — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (193 ) (206 ) (172 ) (4 ) (6 ) (10 ) Amortization of prior service credit (cost) — (1 ) (1 ) 42 49 52 Total recognized in other comprehensive income and regulatory assets and liabilities $ (1,011 ) $ (122 ) $ (151 ) $ (257 ) $ (14 ) $ (54 ) Significant assumptions used to determine periodic cost: Discount rate 2.73%-3.29% 2.77%-3.63% 3.57%-4.43% 2.69%-2.80% 3.07%-3.52% 4.05% to 4.41% Expected long-term rate of return on plan assets 7.00%-8.45% 7.00%-8.60% 7.00% -8.65% 8.45% 8.50% 8.50% Weighted average rate of increase for compensation 4.53% 4.23% 4.20% n/a n/a n/a Crediting interest rate for cash balance and similar plans 1.93%-2.15% 2.31-2.83% 2.77-3.63% n/a n/a n/a Healthcare cost trend rate (1) 6.25% 6.25% 6.50% to 6.60% Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00% 5.00% 5.00% Year that the rate reaches the ultimate trend rate (1) 2026-2027 2025-2026 2023-2025 (1) Assumptions used to determine net periodic cost for the following year. The components of AOCI and regulatory assets and liabilities for Dominion Energy’s plans that have not been recognized as components of net periodic benefit (credit) cost are as follows: Pension Benefits Other Postretirement Benefits At December 31, 2021 2020 2021 2020 (millions) Dominion Energy Net actuarial loss $ 2,198 $ 3,207 $ (166 ) $ 120 Prior service (credit) cost 2 4 (203 ) (232 ) Total (1) $ 2,200 $ 3,211 $ (369 ) $ (112 ) (1) As of December 31, 2021, of the $2.2 billion and $(369) million related to pension benefits and other postretirement benefits, $1.7 billion and $(155) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2020, of the $ billion and $ ( 112 ) million related to pension benefits and other postretirement benefits, $ 1.9 billion and $( 40 ) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. The expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates and mortality are critical assumptions in determining net periodic benefit (credit) cost. Dominion Energy develops non-investment related assumptions, which are then compared to the forecasts of an independent investment advisor to ensure reasonableness. An internal committee selects the final assumptions used for Dominion Energy’s pension and other postretirement plans including discount rates, expected long-term rates of return, healthcare cost trend rates and mortality rates. Dominion Energy determines the expected long-term rates of return on plan assets for its pension plans and other postretirement benefit plans by using a combination of: • Expected inflation and risk-free interest rate assumptions; • Historical return analysis to determine long term historic returns as well as historic risk premiums for various asset classes; • Expected future risk premiums, asset classes’ volatilities and correlations; • Forward-looking return expectations derived from the yield on long-term bonds and the expected long-term returns of major capital market assumptions; and • Investment allocation of plan assets. Dominion Energy determines discount rates from analyses of AA/Aa rated bonds with cash flows matching the expected payments to be made under its plans. Mortality rates are developed from actual and projected plan experience for postretirement benefit plans. Dominion Energy’s actuary conducts an experience study periodically as part of the process to select its best estimate of mortality. Dominion Energy considers both standard mortality tables and improvement factors as well as the plans’ actual experience when selecting a best estimate. Assumed healthcare cost trend rates have a significant effect on the amounts reported for Dominion Energy’s retiree healthcare plans. Dominion Energy establishes the healthcare cost trend rate assumption based on analyses of various factors including the specific provisions of its medical plans, actual cost trends experienced and projected and demographics of plan participants. Virginia Power—Participation in Defined Benefit Plans Virginia Power employees are covered by the Dominion Energy Pension Plan described above. As a participating employer, Virginia Power is subject to Dominion Energy’s funding policy, which is to contribute annually an amount that is in accordance with ERISA. During 2019, Virginia Power made no contributions to the Dominion Energy Pension Plan. During 2020, Virginia Power made a payment to Dominion Energy for $313 million related to its participation in the Dominion Energy Pension Plan. In addition, in December 2020, Dominion Energy notified Virginia Power of a required contribution of $151 million, recorded in payables to affiliates in Virginia Power’s Consolidated Balance Sheets at December 31, 2020, which was paid in 2021. While Virginia Power has not been notified by Dominion Energy of any required contributions to be made in 2022, it anticipates that it may have to contribute approximately $175 million as a result of Dominion Energy’s contribution made in December 2021. Virginia Power’s net periodic pension cost related to this plan was $86 million, $118 million and $152 million in 2021, 2020 and 2019, respectively. Net periodic benefit (credit) cost is reflected in other operations and maintenance expense in Virginia Power’s Consolidated Statements of Income. The funded status of various Dominion Energy subsidiary groups and employee compensation are the basis for determining the share of total pension costs for participating Dominion Energy subsidiaries. See Note 25 for Virginia Power amounts due to/from Dominion Energy related to this plan. Retiree healthcare and life insurance benefits, for Virginia Power employees are covered by the Dominion Energy Retiree Health and Welfare Plan described above. Virginia Power’s net periodic benefit (credit) cost related to this plan was $(72) million, $(58) million and $(27) million in 2021, 2020 and 2019, respectively. Net periodic benefit (credit) cost is reflected in other operations and maintenance expense in Virginia Power’s Consolidated Statements of Income. Employee headcount is the basis for determining the share of total other postretirement benefit costs for participating Dominion Energy subsidiaries. See Note 25 for Virginia Power amounts due to/from Dominion Energy related to this plan. Dominion Energy holds investments in trusts to fund employee benefit payments for the pension and other postretirement benefit plans in which Virginia Power’s employees participate. Any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash that Virginia Power will provide to Dominion Energy for its share of employee benefit plan contributions. Virginia Power funds other postretirement benefit costs through VEBAs. During 2021, 2020 and 2019, Virginia Power made no contributions to the VEBAs and does not expect to contribute to the VEBAs in 2022. Defined Contribution Plans Dominion Energy also sponsors defined contribution employee savings plans that cover substantially all employees. During 2021, 2020 and 2019, Dominion Energy recognized $65 million, $67 million and $69 million, respectively, as employer matching contributions to these plans, excluding discontinued operations. Virginia Power also participates in these employee savings plans. During 2021, 2020 and 2019, Virginia Power recognized $20 million, $19 million and $20 million, respectively, as employer matching contributions to these plans.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	NOTE 23. COMMITMENTS AND CONTINGENCIES As a result of issues generated in the ordinary course of business, the Companies are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. The Companies maintain various insurance programs, including general liability insurance coverage which provides coverage for personal injury or wrongful death cases. 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 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 meet applicable 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. Ozone Standards The EPA published final non-attainment designations for the October 2015 ozone standard in June 2018 with states required to develop plans to address the new standard. Certain states in which the Companies operate have developed plans, and had such plans approved or partially approved by the EPA, which are not expected to have a material impact on the Companies’ results of operations or cash flows. However, until implementation plans for the standard are developed and approved for all states in which the Companies operate, 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. ACE Rule In July 2019, the EPA published the final rule informally referred to as the ACE Rule, as a replacement for the Clean Power Plan. The ACE Rule regulated GHG emissions from existing coal-fired power plants pursuant to Section 111(d) of the CAA and required states to develop plans by July 2022 establishing unit-specific performance standards for existing coal-fired power plants. In January 2021, the U.S. Court of Appeals for the D.C. Circuit vacated the ACE Rule and remanded it to the EPA. This decision would take effect upon issuance of the court’s mandate. In March 2021, the court issued a partial mandate vacating and remanding all parts of the ACE Rule except for the portion of the ACE Rule that repealed the Clean Power Plan. In October 2021, the U.S. Supreme Court agreed to hear a challenge of the U.S. Court of Appeals for the D.C. Circuit’s decision on the ACE Rule. While the EPA has stated its intention to replace the ACE Rule, it is unknown at this time if or how the EPA will issue a replacement for the ACE Rule and how that replacement will affect the Companies’ operations, financial condition and/or cash flows. 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 exceed a significant emissions rate of 75,000 tons per year of CO 2 . In December 2018, the EPA proposed revised Standards of Performance for Greenhouse Gas Emissions from New, Modified, and Reconstructed Stationary Sources. The proposed rule would amend the previous determination that the best system of emission reduction for newly constructed coal-fired steam generating units is no longer partial carbon capture and storage. Instead, the proposed revised best system of emission reduction for this source category is the most efficient demonstrated steam cycle (e.g., supercritical steam conditions for large units and subcritical steam conditions for small units) in combination with best operating practices. In January 2021, the EPA published a final rule affirming that fossil fuel-fired electric generating units meet the requirement that a source category “significantly contribute” to endangering air pollution for the purposes of regulating GHG emissions from new, modified and reconstructed stationary sources. The January 2021 rule also established a threshold for the “significant contribution” threshold that would have meant that no other source category, such as oil and gas facilities, petroleum refineries, and boilers, would meet that requirement at this time. In April 2021, the U.S. Court of Appeals for the D.C. Circuit granted an unopposed motion by the EPA to vacate and remand the January 2021 rule. The proposed revision to the performance standards for coal-fired steam generating units remains pending. Until the EPA ultimately takes final action on this rulemaking, the Companies cannot predict the impact to 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. Regulation 316(b) 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 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, technol ogical , and cost benefit studies. DESC is conducting studies and implementing plans as required by the rule to determine appropriate intake structure modifications at certain facilities to ensure compliance with this rule. While the impacts of this rule could be material to the Companies’ results of operations, financial condition and/or cash flows, the existing regulatory frameworks in South Carolina and Virginia provide rate recovery mechanisms that could substantially mitigate any such impacts for the regulated electric utilities . Effluent Limitations Guidelines 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 established updated standards for wastewater discharges that apply primarily at coal and oil steam generating stations. Affected facilities are required to convert from wet to dry or closed cycle coal ash management, improve existing wastewater treatment systems and/or install new wastewater treatment technologies in order to meet the new discharge limits. In April 2017, the EPA granted two separate petitions for reconsideration of the Effluent Limitations Guidelines final rule and stayed future compliance dates in the rule. Also in April 2017, the U.S. Court of Appeals for the Fifth Circuit granted the EPA’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 was December 2023. In October 2020, the EPA released the final rule that extends the latest dates for compliance. Individual facilities’ compliance dates will vary based on circumstances and the determination by state regulators and may range from 2021 to 2028. While the impacts of this rule could be material to the Companies’ results of operations, financial condition and/or cash flows, the existing regulatory frameworks in South Carolina and Virginia provide rate recovery mechanisms that could substantially mitigate any such impacts for the regulated electric utilities . Waste Management and Remediation The operations of the Companies are subject to a variety of state and federal laws and regulations governing the management and disposal of solid and hazardous waste, and release of hazardous substances associated with current and/or historical operations. The CERCLA, as amended, From time to time, the Companies may be identified as a potentially responsible party in connection with the alleged release of hazardous substances or wastes at a site. Under applicable federal and state laws, the Companies could be responsible for costs associated with the investigation or remediation of impacted sites, or subject to contribution claims by other responsible parties for their costs incurred at such sites. The Companies also may identify, evaluate and remediate other potentially impacted sites under voluntary state programs. insurance policies, rate recovery mechanisms, or both. Except as described below, 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 former manufactured gas plant sites, including certain sites associated with Virginia Power. At 13 sites associated with Dominion Energy, including certain sites acquired in the SCANA Combination, remediation work has been substantially completed under federal or state oversight. Where required, the sites are following state-approved groundwater monitoring programs. Dominion Energy has proposed remediation plans associated with two sites, including one at Virginia Power, and expects to commence remediation activities in 2022 depending on receipt of final permits and approvals. For one site associated with Dominion Energy, final approval of an updated work plan was received from the Army Corps of Engineers in December 2021, resulting in an additional $11 million of reserves and corresponding regulatory assets. At December 31, 2021 and 2020, Dominion Energy had $45 million and $42 million, respectively, of reserves recorded. Dominion Energy’s reserves include charges of $14 million ($11 million after-tax) recorded in 2020, in other operations and maintenance expense in the Consolidated Statements of Income. At December 31, 2021 and 2020, Virginia Power had $25 million and $26 million, respectively, of reserves recorded. Virginia Power’s reserves include charges of $10 million ($7 million after-tax) recorded in 2020, in other operations and maintenance expense in the Consolidated Statements of Income. Dominion Energy is associated with 12 additional sites, including two associated with Virginia Power, which are not under investigation by any state or federal environmental agency nor the subject of any current or proposed plans to perform remediation activities. Due to the uncertainty surrounding such sites, the Companies are unable to make an estimate of the potential financial statement impacts. 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. SCANA Legal Proceedings The following describes certain legal proceedings involving Dominion Energy, SCANA or DESC relating primarily to events occurring before closing of the SCANA Combination. No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material. For certain of these matters, and unless otherwise noted therein, Dominion Energy is unable to estimate a reasonable range of possible loss and the related financial statement impacts, but for any such matter there could be a material impact to its results of operations, financial condition and/or cash flows. For the matters for which Dominion Energy is able to reasonably estimate a probable loss, Dominion Energy’s Consolidated Balance Sheets at December 31, 2021 and 2020 include reserves of $274 million and $208 million, respectively, included in other current liabilities, and insurance receivables of $118 million and $8 million, respectively, included within other receivables. These balances at December 31, 2021 and 2020 include $85 $8 Ratepayer Class Actions In May 2018, a consolidated complaint against DESC, SCANA and the State of South Carolina was filed in the State Court of Common Pleas in Hampton County, South Carolina (the DESC Ratepayer Case). The plaintiffs alleged, among other things, that DESC was negligent and unjustly enriched, breached alleged fiduciary and contractual duties and committed fraud and misrepresentation in failing to properly manage the NND Project, and that DESC committed unfair trade practices and violated state anti-trust laws. In December 2018, the State Court of Common Pleas in Hampton County entered an order granting preliminary approval of a class action settlement. The court entered an order granting final approval of the settlement in June 2019, which became effective in July 2019. The settlement agreement, contingent upon the closing of the SCANA Combination, provided that SCANA and DESC establish an escrow account and proceeds from the escrow account would be distributed to the plaintiffs, after payment of certain taxes, attorneys' fees and other expenses and administrative costs. The escrow account would include (1) up to $2.0 billion, net of a credit of up to $2.0 billion in future electric bill relief, which would inure to the benefit of the escrow account in favor of class members over a period of time established by the South Carolina Commission in its order related to matters before the South Carolina Commission related to the NND Project, (2) a cash payment of $115 million and (3) the transfer of certain DESC-owned real estate or sales proceeds from the sale of such properties, which counsel for the plaintiffs estimated to have an aggregate value between $60 million and $85 million. At the closing of the SCANA Combination, SCANA and DESC funded the cash payment portion of the escrow account. In July 2019, DESC transferred $117 million representing the cash payment, plus accrued interest, to the plaintiffs. Through August 2020, property, plant and equipment with a net recorded value of $27 million had been transferred to the plaintiffs in coordination with the court-appointed real estate trustee to satisfy the settlement agreement. In September 2020, the court entered an order approving a final resolution of the transfer of real estate or sales proceeds with a cash contribution of $38.5 million by DESC and the conveyance of property, plant and equipment with a net recorded value of $3 million, which was completed by DESC in October 2020. In December 2021, the court approved a motion for and DESC completed the repurchase of $8 million of property, plant and equipment previously transferred to the plaintiffs. In September 2017, a purported class action was filed by Santee Cooper ratepayers against Santee Cooper, DESC, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. in the State Court of Common Pleas in Hampton County, South Carolina (the Santee Cooper Ratepayer Case). The allegations were substantially similar to those in the DESC Ratepayer Case. In March 2020, the parties executed a settlement agreement relating to this matter as well as the Luquire Case and the Glibowski Case described below. The settlement agreement provided that Dominion Energy and Santee Cooper establish a fund for the benefit of class members in the amount of $520 million, of which Dominion Energy’s portion was $320 million of shares of Dominion Energy common stock. In July 2020, the court issued a final approval of the settlement agreement. In September 2020, Dominion Energy issued $322 million of shares of Dominion Energy common stock to satisfy its obligation under the settlement agreement, including interest charges. In July 2019, a similar purported class action was filed by certain Santee Cooper ratepayers against DESC, SCANA, Dominion Energy and former directors and officers of SCANA in the State Court of Common Pleas in Orangeburg, South Carolina (the Luquire Case). In August 2019, DESC, SCANA and Dominion Energy were voluntarily dismissed from the case. The claims were similar to the Santee Cooper Ratepayer Case. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Glibowski Case. This case was dismissed as part of the Santee Cooper Ratepayer Case settlement described above. RICO Class Action In January 2018, a purported class action was filed, and subsequently amended, against SCANA, DESC and certain former executive officers in the U.S. District Court for the District of South Carolina (the Glibowski Case). The plaintiff alleged, among other things, that SCANA, DESC and the individual defendants participated in an unlawful racketeering enterprise in violation of RICO and conspired to violate RICO by fraudulently inflating utility bills to generate unlawful proceeds. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Luquire Case. This case was dismissed as part of the Santee Cooper Ratepayer Case settlement described above. SCANA Shareholder Litigation In September 2017, a purported class action was filed against SCANA and certain former executive officers and directors in the U.S. District Court for the District of South Carolina. Subsequent additional purported class actions were separately filed against all or nearly all of these defendants (collectively the SCANA Securities Class Action). In January 2018, the U.S. District Court for the District of South Carolina consolidated these suits, and the plaintiffs filed a consolidated amended complaint in March 2018. The plaintiffs alleged, among other things, that the defendants violated §10(b) of the Securities Exchange Act of 1934, as amended, and Rule 10b-5 promulgated thereunder, and that the individually named defendants are liable under §20(a) of the same act. In December 2019, the parties executed a settlement agreement pursuant to which SCANA would pay $192.5 million, up to $32.5 million of which could be satisfied through the issuance of shares of Dominion Energy common stock, subject to court approval. In February 2020, the U.S. District Court for the District of South Carolina granted preliminary approval of the settlement agreement, pending a fairness hearing, and granted final approval in July 2020. In March 2020, SCANA funded an escrow account with $160 million in cash and paid the balance of $32.5 million in cash in August 2020 to satisfy the settlement. In September 2017, a shareholder derivative action was filed against certain former executive officers and directors of SCANA in the State Court of Common Pleas in Richland County, South Carolina (the State Court Derivative Case). In September 2018, this action was consolidated with another action in the Business Court Pilot Program in Richland County. The plaintiffs allege, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the NND Project, and that the defendants were unjustly enriched by bonuses they were paid in connection with the project. In January 2019, the defendants filed a motion to dismiss the consolidated action. In February 2019, one action was voluntarily dismissed. In March 2020, the court denied the defendants’ motion to dismiss. In April 2020, the defendants filed a notice of appeal with the South Carolina Court of Appeals and a petition with the Supreme Court of South Carolina seeking appellate review of the denial of the motion to dismiss. In June 2020, the plaintiffs filed a motion to dismiss the appeal with the South Carolina Court of Appeals, which was granted in July 2020. In August 2020, the Supreme Court of South Carolina denied the defendants’ petition seeking appellate review. Also in August 2020, the defendants filed a petition for rehearing with the South Carolina Court of Appeals relating to the July 2020 ruling by the court, which was denied in October 2020. In November 2020, SCANA filed a petition of certiorari with the Supreme Court of South Carolina seeking appellate review of the denial of SCANA’s motion to dismiss. This petition was denied in June 2021. Also in June 2021, the parties reached an agreement in principle in the amount of $33 million to resolve this matter, subject to court approval. This settlement was reached in contemplation of and will be utilized to satisfy a portion of the Federal Court Merger Case and the State Court Merger Case discussed below. In November 2021, the parties executed a settlement agreement and filed with the State Court of Common Pleas in Richland County, South Carolina for approval. In January 2018, a purported class action was filed against SCANA, Dominion Energy and certain former executive officers and directors of SCANA in the State Court of Common Pleas in Lexington County, South Carolina (the City of Warren Lawsuit). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the merger. In February 2018, a purported class action was filed against Dominion Energy and certain former directors of SCANA and DESC in the State Court of Common Pleas in Richland County, South Carolina (the Metzler Lawsuit). The allegations made and the relief sought by the plaintiffs are substantially similar to that described for the City of Warren Lawsuit. In September 2019, the U.S. District Court for the District of South Carolina granted the plaintiffs’ motion to consolidate the City of Warren Lawsuit and the Metzler Lawsuit (the Federal Court Merger Case). In October 2019, the plaintiffs filed an amended complaint against certain former directors and executive officers of SCANA and DESC, which stated substantially similar allegations to those in the City of Warren Lawsuit and the Metzler Lawsuit as well as an inseparable fraud claim. In November 2019, the defendants filed a motion to dismiss. In April 2020, the U.S. District Court for the District of South Carolina denied the motion to dismiss. In May 2020, SCANA filed a motion to intervene, which was denied in August 2020. In September 2020, SCANA filed a notice of appeal with the U.S. Court of Appeals for the Fourth Circuit. In June 2021, the parties reached an agreement in principle in the amount of $63 million to resolve this matter as well as the State Court Merger Case described below, subject to court approval. This settlement was reached in contemplation of and will be partially satisfied by the State Court Derivative Case settlement described above. In November 2021, the parties executed a settlement agreement, as described above relating to this matter as well as the State Court Derivative Case and the State Court Merger Case, and filed with the State Court of Common Pleas in Richland County, South Carolina for approval. In May 2019, a case was filed against certain former executive officers and directors of SCANA in the State Court of Common Pleas in Richland County, South Carolina (the State Court Merger Case). The plaintiff alleges, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the NND Project, were unjustly enriched by the bonuses they were paid in connection with the project and breached their fiduciary duties to secure and obtain the best price for the sale of SCANA. Also in May 2019, the case was removed to the U.S. District Court of South Carolina by the non-South Carolina defendants. In June 2019, the plaintiffs filed a motion to remand the case to state court. In January 2020, the case was remanded to state court. In February 2020, the defendants filed a motion to dismiss. In June 2021, the parties reached an agreement in principle as described above relating to this matter as well as the Federal Court Merger Case and the State Court Derivative Case. In November 2021, the parties executed a settlement agreement, as described above relating to this matter as well as the State Court Derivative Case and the Federal Court Merger Case, and filed with the State Court of Common Pleas in Richland County, South Carolina for approval. Employment Class Actions and Indemnification In August 2017, a case was filed in the U.S. District Court for the District of South Carolina on behalf of persons who were formerly employed at the NND Project. In July 2018, the court certified this case as a class action. In February 2019, certain of these plaintiffs filed an additional case, which case has been dismissed and the plaintiffs have joined the case filed August 2017. The plaintiffs allege, among other things, that SCANA, DESC, Fluor Corporation In September 2018, a case was filed in the State Court of Common Pleas in Fairfield County, South Carolina by Fluor Enterprises, Inc. and Fluor Daniel Maintenance Services, Inc. against DESC and Santee Cooper. The plaintiffs make claims for indemnification, breach of contract and promissory estoppel arising from, among other things, the defendants' alleged failure and refusal to defend and indemnify the Fluor defendants in the aforementioned case. This case is pending. FILOT Litigation and Related Matters In November 2017, Fairfield County filed a complaint and a motion for temporary injunction against DESC in the State Court of Common Pleas in Fairfield County, South Carolina, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of implied duty of good faith and fair dealing and unfair trade practices related to DESC’s termination of the FILOT agreement between DESC and Fairfield County related to the NND Project. The plaintiff sought a temporary and permanent injunction to prevent DESC from terminating the FILOT agreement. The plaintiff withdrew the motion for temporary injunction in December 2017. In July 2021, the parties executed a settlement agreement requiring DESC to pay $99 million, which could be satisfied in either cash or shares of Dominion Energy common stock. Also in July 2021, the State Court of Common Pleas in Fairfield County, South Carolina approved the settlement. In July 2021, Dominion Energy issued 1.4 million shares of Dominion Energy common stock to satisfy DESC’s obligation under the settlement agreement. Governmental Proceedings and Investigations In June 2018, DESC received a notice of proposed assessment of approximately $410 million, excluding interest, from the SCDOR following its audit of DESC’s sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The proposed assessment, which includes 100% of the NND Project, is based on the SCDOR’s position that DESC’s sales and use tax exemption for the NND Project does not apply because the facility will not become operational. In December 2020, the parties reached an agreement in principle in the amount of $165 million to resolve this matter. In June 2021, the parties executed a settlement agreement which allows DESC to fund the settlement amount through a combination of cash, shares of Dominion Energy common stock or real estate with an initial payment of at least $43 million in shares of Dominion Energy common stock. In August 2021, Dominion Energy issued 0.6 million shares of its common stock to satisfy DESC’s obligation for the initial payment under the settlement agreement. In September and October 2017, SCANA was served with subpoenas issued by the U.S. Attorney’s Office for the District of South Carolina and the Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. In February 2020, the SEC filed a complaint against SCANA, two of its former executive officers and DESC in the U.S. District Court for the District of South Carolina alleging that the defendants violated federal securities laws by making false and misleading statements about the NND Project. In April 2020, SCANA and DESC reached an agreement in principle with the Staff of the SEC’s Division of Enforcement to settle, without admitting or denying the allegations in the complaint. In December 2020, the U.S. District Court for the District of South Carolina issued an order approving the settlement which required SCANA to pay a civil monetary penalty totaling $25 million, and SCANA and DESC to pay disgorgement and prejudgment interest totaling $112.5 million, which disgorgement and prejudgment interest amount were deemed satisfied by the settlements in the SCANA Securities Class Action and the DESC Ratepayer Case. SCANA paid the civil penalty in December 2020. The SEC civil action against two former executive officers of SCANA remains pending and is currently subject to a stay granted by the court in June 2020 at the request of the U.S. Attorney’s Office for the District of South Carolina. In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and DESC. Dominion Energy is cooperating fully with the investigations by the U.S. Attorney’s Office and the South Carolina Law Enforcement Division, including responding to additional subpoenas and document requests. Dominion Energy has also entered into a cooperation agreement with the U.S. Attorney’s Office and the South Carol

Credit Risk

Credit Risk	12 Months Ended
	Dec. 31, 2021
Risks And Uncertainties [Abstract]
Credit Risk	NOTE 24. CREDIT RISK Dominion Energy As a diversified energy company, Dominion Energy transacts primarily with major companies in the energy industry and with commercial and residential energy consumers. These transactions principally occur in the Northeast, mid-Atlantic, Midwest and Rocky Mountain and Southeast regions of the U.S. Dominion Energy does not believe that this geographic concentration contributes significantly to its overall exposure to credit risk. In addition, as a result of its large and diverse customer base, Dominion Energy is not exposed to a significant concentration of credit risk for receivables arising from electric and gas utility operations. Dominion Energy’s exposure to credit risk is concentrated primarily within its energy marketing and price risk management activities, as Dominion Energy transacts with a smaller, less diverse group of counterparties and transactions may involve large notional volumes and potentially volatile commodity prices. Energy marketing and price risk management activities include marketing of nonregulated generation output, structured transactions and the use of financial contracts for enterprise-wide hedging purposes. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of any collateral. At December 31, 2021, Dominion Energy’s credit exposure totaled $152 million. Of this amount, investment grade counterparties, including those internally rated, represented 85%, and no single counterparty, whether investment grade or non-investment grade, exceeded $45 million of exposure. Virginia Power Virginia Power sells electricity and provides distribution and transmission services to customers in Virginia and northeastern North Carolina. Management believes that this geographic concentration risk is mitigated by the diversity of Virginia Power’s customer base, which includes residential, commercial and industrial customers, as well as rural electric cooperatives and municipalities. Credit risk associated with trade accounts receivable from energy consumers is limited due to the large number of customers. Virginia Power’s exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Virginia Power’s gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of collateral. At December 31, 2021, Virginia Power’s credit exposure totaled $16 million. Of this amount, investment grade counterparties, including those internally rated, represented 47%, and no single counterparty exceeded $4 million of exposure. Credit-Related Contingent Provisions Certain of Dominion Energy’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion Energy to provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered, as of December 31, 2021 and 2020 Dominion Energy would have been required to post $31 million and $14 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 $66 million and $1 million of collateral at December 31, 2021 and 2020, respectively, 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 as of December 31, 2021 and 2020 was $97 million and $15 million, respectively, which does not include the impact of any offsetting asset positions. Certain of Virginia Power’s derivative instruments contain credit-related contingent provisions. These provisions require Virginia Power to provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered as of December 31, 2021 and 2020, Virginia Power would have been required to post an additional $22 million and $2 million, respectively, of additional collateral to its counterparties. The collateral that would be required to be posted includes the impacts of any offsetting asset position and any amounts already posted for derivatives and non-derivative contracts, per contractual terms. Virginia Power had posted $54 million of collateral at December 31, 2021 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. No such amounts were posted at December 31, 2020. 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 was $76 million and $2 million at December 31, 2021 and December 31, 2020, respectively, which does not include the impact of any offsetting asset positions. See Note 7 for further information about derivative instruments.

Related-Party Transactions

Related-Party Transactions	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Related-Party Transactions	NOTE 25. RELATED-PARTY TRANSACTIONS Virginia Power engages in related party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia Power’s receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Virginia Power is included in Dominion Energy’s consolidated federal income tax return and, where applicable, combined income tax returns for Dominion Energy are filed in various states. See Note 2 for further information. Dominion Energy’s transactions with equity method investments are described in Note 9. A discussion of significant related party transactions follows. 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 forward commodity purchases, to manage commodity price risks associated with purchases of natural gas. See Notes 7 and 20 for more information. At December 31, 2021, Virginia Power’s derivative assets and liabilities with affiliates were $29 million and $6 million, respectively. At December 31, 2020, Virginia Power’s derivative assets and liabilities with affiliates were $3 million and $22 million, respectively. Virginia Power participates in certain Dominion Energy benefit plans as described in Note 22. 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: Year Ended December 31, 2021 2020 2019 (millions) Commodity purchases from affiliates $ 742 $ 569 $ 690 Services provided by affiliates (1) 494 455 503 Services provided to affiliates 18 18 24 (1) Includes capitalized expenditures of $161 million, $141 million and $133 million for the year ended December 31, 2021, 2020 and 2019, respectively. Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were $699 million and $380 million in short-term demand note borrowings from Dominion Energy as of December 31, 2021 and 2020, respectively. The weighted-average interest rate of these borrowings was 0.26% and 0.30% at December 31, 2021 and 2020, respectively. Virginia Power had no outstanding borrowings, net of repayments under the Dominion Energy money pool for its nonregulated subsidiaries as of December 31, 2021 and 2020. Interest charges related to Virginia Power’s borrowings from Dominion Energy were immaterial for the years ended December 31, 2021, 2020 and 2019. There were no issuances of Virginia Power’s common stock to Dominion Energy in 2021, 2020 or 2019.

Operating Segments

Operating Segments	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Operating Segments	NOTE 26. 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 Virginia Regulated electric distribution X X Regulated electric transmission X X Regulated electric generation fleet (1) X X Gas Distribution Regulated gas distribution and storage (2) X Dominion Energy South Carolina Regulated electric distribution X Regulated electric transmission X Regulated electric generation fleet X Regulated gas distribution and storage X Contracted Assets Nonregulated electric generation fleet (3) X Noncontrolling interest in Cove Point X (1) I ncludes Virginia Power’s non-jurisdictional generation operations. (2) (3) Includes solar generation facility development operations. 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 companies and other functions (including unallocated debt) as well as nonregulated retail energy marketing operations (prior to December 1, 2021) , including Dominion Energy’s noncontrolling interest in Wrangler. 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, as well as the net impact of the gas transmission and storage operations held in discontinued operations which are discussed in Note 3. In 2021, Dominion Energy reported after-tax net expenses of $99 million in the Corporate and Other segment, including $97 million of after-tax net benefit for specific items with $493 million of after tax-net expenses attributable to its operating segments. The net expenses for specific items attributable to Dominion Energy’s operating segments in 2021 primarily related to the impact of the following items: • A $347 million ($261 million after-tax) loss related to economic hedging activities, attributable to Contracted Assets; • $266 million ($199 million after-tax) of charges associated with the settlement of the South Carolina electric base rate case, attributable to Dominion Energy South Carolina ; • A $211 million ($161 million after-tax) net loss on the sale of non-wholly-owned nonregulated solar facilities, attributable to Contracted Assets; • A $ 151 • A $125 million ($93 million after-tax) net charge associated with the settlement of the 2021 Triennial Review, attributable to Dominion Energy Virginia; • A $77 million ($57 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to Virginia’s 2021 budget process, attributable to Dominion Energy Virginia; • A $70 million ($53 million after-tax) charge associated with litigation acquired in the SCANA Combination, attributable to Dominion Energy South Carolina; • A $68 million ($50 million after-tax) charge associated with storm damage and service restoration in Virginia Power’s service territory, attributable to Dominion Energy Virginia; • A $61 million ($45 million after-tax) charge for amortization of a regulatory asset established in connection with the settlement of the 2021 Triennial Review, attributable to Dominion Energy Virginia; and • A $44 million ($35 million after-tax) charge related to a revision in estimated recovery of spent nuclear fuel costs associated with the decommissioning of Kewaunee, attributable to Contracted Assets; partially offset by • A $568 million ($445 million after-tax) gain related to investments in nuclear decommissioning trust funds, attributable to: • Contracted Assets ($390 million after-tax); and • Dominion Energy Virginia ($55 million after-tax); and • A $130 million ($97 million after-tax) benefit for a change in the expected CCRO to be provided to Virginia retail electric customers under the GTSA, attributable to Dominion Energy Virginia. In 2020, Dominion Energy reported after-tax net expenses of $3.7 billion in the Corporate and Other segment, including $3.4 billion of after-tax net expenses for specific items with $1.2 billion of after-tax net expenses attributable to its operating segments. The net expenses for specific items attributable to Dominion Energy’s operating segments in 2020 primarily related to the impact of the following items: • A $751 million ($564 million after-tax) charge primarily related to the planned early retirement of certain Virginia Power electric generation facilities, attributable to Dominion Energy Virginia; • A $405 million ($325 million after-tax) charge associated with certain nonregulated solar generation facilities, attributable to Contracted Assets; • A $221 million ($171 million after-tax) charge associated with the sale of Fowler Ridge, attributable to Contracted Assets; and • A $130 million ($97 million after-tax) charge for the expected CCRO to be provided to Virginia retail electric customers under the GTSA, attributable to Dominion Energy Virginia; • A $127 million ($94 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to legislation enacted in November 2020, attributable to Dominion Energy Virginia; and • A $ 117 million ($ 93 million after-tax) of charges associated with litigation acquired in the SCANA Combination, attributable to Dominion Energy South Carolina; partially offset by • A $335 million ($264 million after-tax) net gain related to investments in nuclear decommissioning trust funds attributable to: • Dominion Energy Virginia ($27 million after-tax); and • Contracted Assets ($237 million after-tax). In 2019, Dominion Energy reported after-tax net expenses of $1.8 billion in the Corporate and Other segment, including $1.5 billion of after-tax net expenses for specific items with $1.9 billion of after-tax net expenses attributable to its operating segments. The net expenses for specific items attributable to Dominion Energy’s operating segments in 2019 primarily related to the impact of the following items: • A $1.0 billion ($756 million after-tax) charge for refunds of amounts previously collected from retail electric customers of DESC for the NND Project, attributable to Dominion Energy South Carolina; • $641 million ($480 million after-tax) of charges associated with litigation acquired in the SCANA Combination, attributable to Dominion Energy South Carolina; • $427 million ($320 million after-tax) of charges for merger and integration-related costs associated with the SCANA Combination, including a $394 million ($295 million after-tax) charge related to a voluntary retirement program, attributable to: • Dominion Energy Virginia ($151 million after-tax); • Gas Distribution ($56 million after-tax); • Dominion Energy South Carolina ($75 million after-tax); and • Contracted Assets ($38 million after-tax). • A $346 million ($257 million after-tax) charge related to the early retirement of certain Virginia Power electric generation facilities, attributable to Dominion Energy Virginia; • A $194 million tax charge for $258 million of income tax-related regulatory assets acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery, attributable to Dominion Energy South Carolina; • A $160 million ($119 million after-tax) charge related to Virginia Power’s planned early retirement of certain automated meter reading infrastructure, attributable to Dominion Energy Virginia; • A $135 million ($100 million after-tax) charge related to Virginia Power’s contract termination with a non-utility generator, attributable to Dominion Energy Virginia; • A $114 million ($86 million after-tax) charge for property, plant and equipment acquired in the SCANA Combination primarily for which Dominion Energy committed to forgo recovery, attributable to Dominion Energy South Carolina; partially offset by • A $553 million ($411 million after-tax) net gain related to investments in nuclear decommissioning trust funds attributable to: • Dominion Energy Virginia ($49 million after-tax); and • Contracted Assets ($362 million after-tax); and • A $113 million ($84 million after-tax) benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019, attributable to Dominion Energy Virginia. The following table presents segment information pertaining to Dominion Energy’s operations: Year Ended December 31, Dominion Energy Virginia Gas Distribution Dominion Energy South Carolina Contracted Assets Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2021 Total revenue from external customers $ 8,012 $ 2,660 $ 2,968 $ 1,018 $ (759 ) $ 60 $ 13,959 Intersegment revenue (13 ) 5 7 67 943 (1,004 ) 5 Total operating revenue 7,999 2,665 2,975 1,085 184 (944 ) 13,964 Depreciation, depletion and amortization 1,299 380 486 162 151 — 2,478 Equity in earnings of equity method investees — — (3 ) 259 20 — 276 Interest income 13 6 10 81 17 (26 ) 101 Interest and related charges 537 86 206 52 499 (26 ) 1,354 Income tax expense (benefit) 462 116 125 112 (390 ) — 425 Net income from discontinued operations — — — — 641 — 641 Net income (loss) attributable to Dominion Energy 1,919 600 437 431 (99 ) — 3,288 Investment in equity method investees (1) — 106 — 2,738 88 — 2,932 Capital expenditures 3,762 1,252 694 277 76 — 6,061 Total assets (billions) 50.3 18.5 16.4 12.3 7.1 (5.0 ) 99.6 2020 Total revenue from external customers $ 7,802 $ 2,345 $ 2,782 $ 1,020 $ 200 $ 48 $ 14,197 Intersegment revenue (15 ) 10 5 51 963 (1,039 ) (25 ) Total operating revenue 7,787 2,355 2,787 1,071 1,163 (991 ) 14,172 Depreciation, depletion and amortization 1,247 344 474 182 85 — 2,332 Equity in earnings of equity method investees — — (1 ) 35 6 — 40 Interest income 13 6 12 91 73 (88 ) 107 Interest and related charges 527 76 219 75 568 (88 ) 1,377 Income tax expense (benefit) 496 121 107 (16 ) (625 ) — 83 Net income (loss) from discontinued operations — — — 167 (2,045 ) — (1,878 ) Net income (loss) attributable to Dominion Energy 1,891 560 419 402 (3,673 ) — (401 ) Investment in equity method investees (1) — 55 — 2,784 95 — 2,934 Capital expenditures 3,406 1,151 700 649 425 — 6,331 Total assets (billions) 46.0 17.1 16.0 13.1 8.6 (4.9 ) 95.9 2019 Total revenue from external customers $ 8,170 $ 2,367 $ 2,948 $ 1,083 $ (239 ) $ 79 $ 14,408 Intersegment revenue (13 ) 18 4 73 1,071 (1,160 ) (7 ) Total operating revenue 8,157 2,385 2,952 1,156 832 (1,081 ) 14,401 Depreciation, depletion and amortization 1,216 335 452 180 100 — 2,283 Equity in earnings of equity method investees — 2 (4 ) (1 ) 11 — 8 Interest income 11 4 9 97 112 (136 ) 97 Interest and related charges 530 116 242 98 636 (136 ) 1,486 Income tax expense (benefit) 482 114 163 20 (570 ) — 209 Net income from discontinued operations — — — 183 533 — 716 Net income (loss) attributable to Dominion Energy 1,786 487 430 460 (1,805 ) — 1,358 Capital expenditures 3,002 853 562 367 537 — 5,321 (1) Excludes liability to Atlantic Coast Pipeline. 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, including amounts related to entities presented within discontinued operations. Virginia Power The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance or in allocating resources. In 2021, Virginia Power reported after-tax net expenses of $202 million in the Corporate and Other segment, including $202 million of after-tax net expenses for specific items all of which were attributable to its operating segment. The net expenses for specific items attributable to its operating segment in 2021 primarily related to the impact of the following items: • A $151 million ($112 million after-tax) loss from an unbilled revenue reduction; • A $125 million ($93 million after-tax) net charge associated with the settlement of the 2021 Triennial Review; • A $77 million ($57 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to Virginia’s 2021 budget process; • A $68 million ($50 million after-tax) charge associated with storm damage and service restoration in its service territory; and • A $61 million ($45 million after-tax) charge for amortization of a regulatory asset established in connection with the settlement of the 2021 Triennial Review; partially offset by • A $130 million ($97 million after-tax) benefit for a change in the expected CCRO to be provided to Virginia retail electric customers under the GTSA. In 2020, Virginia Power reported after-tax net expenses of $863 million in the Corporate and Other segment, including $915 million of after-tax net expenses for specific items all of which were attributable to its operating segment. The net expenses for specific items attributable to its operating segment in 2020 primarily related to a $751 million ($559 million after-tax) charge related to the planned early retirement of certain electric generation facilities, a $130 million ($97 million after-tax) charge for the expected CCRO to be provided to Virginia retail electric customers under the GTSA and a $127 million ($94 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to legislation enacted in November 2020. In 2019, Virginia Power reported after-tax net expenses of $634 million in the Corporate and Other segment, including $627 million of after-tax net expenses for specific items all of which were attributable to its operating segment. The net expenses for specific items attributable to its operating segment in 2019 primarily related to the impact of the following items: • A $346 million ($257 million after-tax) charge related to the early retirement of certain electric generation facilities; • A $198 million ($146 million after-tax) charge related to a voluntary retirement program; • A $160 million ($119 million after-tax) charge related to the planned early retirement of certain automated meter reading infrastructure; • A $135 million ($100 million after-tax) charge related to a contract termination with a non-utility generator; and • A $62 million ($46 million after-tax) charge related to the abandonment of a project at an electric generating facility; partially offset by • A $113 million ($84 million after-tax) benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019. The following table presents segment information pertaining to Virginia Power’s operations: Year Ended December 31, Dominion Energy Virginia Corporate and Other Consolidated Total (millions) 2021 Operating revenue $ 7,976 $ (506 ) $ 7,470 Depreciation and amortization 1,296 68 1,364 Interest income 11 — 11 Interest expense (benefit) and related charges 535 (1 ) 534 Income tax expense (benefit) 467 (70 ) 397 Net income (loss) 1,914 (202 ) 1,712 Capital expenditures 3,756 — 3,756 Total assets (billions) 47.9 — 47.9 2020 Operating revenue $ 7,763 $ — $ 7,763 Depreciation and amortization 1,245 7 1,252 Interest income 11 — 11 Interest expense (benefit) and related charges 524 (8 ) 516 Income tax expense (benefit) 500 (271 ) 229 Net income (loss) 1,884 (863 ) 1,021 Capital expenditures 3,372 — 3,372 Total assets (billions) 43.7 — 43.7 2019 Operating revenue $ 8,137 $ (29 ) $ 8,108 Depreciation and amortization 1,215 8 1,223 Interest income 11 — 11 Interest expense (benefit) and related charges 529 (5 ) 524 Income tax expense (benefit) 481 (217 ) 264 Net income (loss) 1,783 (634 ) 1,149 Capital expenditures 2,981 — 2,981

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Estimates	The Companies make certain estimates and assumptions in preparing their Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses and cash flows for the periods presented. Actual results may differ from those estimates.
Consolidation	The Companies’ Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned 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. Clearway’s ownership interest in Four Brothers and Three Cedars (through December 2021), Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy nonregulated solar projects (through December 2021), Brookfield’s 25% interest in Cove Point (effective December 2019 until November 2020) and the non-Dominion Energy held interest in Dominion Energy Midstream (through January 2019) are reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements.
Reclassifications	Certain amounts in the Companies’ 2020 and 2019 Consolidated Financial Statements and Notes have been reclassified to conform to the 2021 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows. Effective in the second quarter of 2021, the Companies updated their Statements of Cash Flows to present net charges for allowance for credit risk and write-offs of accounts receivables within other adjustments to reconcile net income to net cash provided by operating activities from the previous presentation within changes in accounts receivable. All prior period information has been conformed to this presentation, which does not result in a change to net cash provided by operating activities. Amounts disclosed for Dominion Energy are inclusive of Virginia Power, where applicable.
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. The Companies collect sales, consumption and consumer utility taxes; however, these amounts are excluded from revenue. Dominion Energy’s customer receivables at December 31, 2021 and 2020 included $779 million and $1.1 billion, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power’s customer receivables at December 31, 2021 and 2020 included $398 million and $740 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers. See Note 25 for amounts attributable to related parties. The primary types of sales and service activities reported as operating revenue for Dominion Energy 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 and sales to Virginia Power customers from non-jurisdictional solar generation facilities; • 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 state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers, sales of gathering services and sales of transportation services to off-system customers; • 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 sales of commodities related to nonregulated extraction activities and other miscellaneous products. Other nonregulated revenue also includes sales of energy-related products and services from Dominion Energy’s retail energy marketing operations (through December 2021), service concession arrangements and revenue associated with services provided to entities presented in discontinued operations under transition services agreements. 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 Virginia Power 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 consists of sales to customers from non-jurisdictional solar generation facilities; • 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 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, gains and losses from derivative instruments not subject to hedge accounting and lease revenues. The Companies record refunds to customers as required by state commissions as a reduction to regulated electric sales or regulated gas sales, as applicable. The Companies’ revenue accounted for under the alternative revenue program guidance primarily consists of the equity return for under-recovery of certain riders. Alternative revenue programs compensate the Companies for certain projects and initiatives. Revenues arising from these programs are presented separately from revenue arising from contracts with customers in the categories above. Revenues from electric and gas sales are recognized over time, as the customers of the Companies consume gas and electricity as it is delivered. 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 has 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 and services typically transfer control and are recognized as revenue upon delivery of the product or service. 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. Operating revenue for the gas transmission and storage operations sold to BHE as part of the GT&S Transaction and sold to Southwest Gas as part of the Q-Pipe Group sale primarily consisted of FERC-regulated sales of transmission and storage services, LNG terminalling services, sales of extracted products and associated hedging activities and NGL activities, including gathering and processing and sales of production and condensate as well as services performed for Atlantic Coast Pipeline. This revenue is included in discontinued operations in Dominion Energy’s Consolidated Statements of Income. Transportation and storage contracts associated with the operations sold to BHE as part of the GT&S Transaction and sold to Southwest Gas as part of the Q-Pipe Group sale were primarily stand-ready service contracts that include fixed reservation and variable usage fees. LNG terminalling services, included in discontinued operations, are also stand-ready service contracts, primarily consisting of fixed fees, offset by service credits associated with the start-up phase of the Liquefaction Facility. NGLs received during natural gas processing are recorded in discontinued operations at fair value as service revenue recognized over time, and revenue continued to be recognized from the subsequent sale of the NGLs to customers upon delivery.
Credit Risk	Credit Risk Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction. The Companies maintain a provision for credit losses based on factors surrounding the credit risk of their customers, historical trends and other information. Effective January 2020, expected credit losses are estimated and recorded based on historical experience, current conditions and reasonable and supportable forecasts that affect the collectability of financial assets held at amortized cost as well as expected credit losses on commitments with respect to financial guarantees.
Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs Where permitted by regulatory authorities, the differences between the Companies’ actual electric fuel and purchased energy expenses and Dominion Energy’s purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability. Of the cost of fuel used in electric generation and energy purchases to serve Virginia utility customers, at December 31, 2021, approximately 86% is subject to Virginia Power’s deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms. Of the cost of fuel used in electric generation and energy purchases to serve South Carolina utility customers, at December 31, 2021, approximately 96% is subject to DESC’s deferred fuel accounting. Virtually all of East Ohio, Questar Gas, Hope, DESC and PSNC’s natural gas purchases are either subject to deferral accounting or are recovered from the customer in the same accounting period as the sale.
Income Taxes	Income Taxes A consolidated federal income tax return is filed for Dominion Energy and its subsidiaries, including Virginia Power. In addition, where applicable, combined income tax returns for Dominion Energy and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Virginia Power participates in intercompany tax sharing agreements with Dominion Energy and its subsidiaries. Current income taxes are based on taxable income or loss and credits determined on a separate company basis. Under the agreements, if a subsidiary incurs a tax loss or earns a credit, recognition of current income tax benefits is limited to refunds of prior year taxes obtained by the carryback of the net operating loss or credit or to the extent the tax loss or credit is absorbed by the taxable income of other Dominion Energy consolidated group members. Otherwise, the net operating loss or credit is carried forward and is recognized as a deferred tax asset until realized. Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Accordingly, deferred taxes are recognized for the future consequences of different treatments used for the reporting of transactions in financial accounting and income tax returns. The Companies establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities. The Companies recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information. If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the Consolidated Balance Sheets and current payables are included in accrued interest, payroll and taxes on the Consolidated Balance Sheets. The Companies recognize interest on underpayments and overpayments of income taxes in interest expense and other income, respectively. Penalties are also recognized in other income. In 2021, Dominion Energy reflected a $21 million benefit from the reversal of interest expense and a $7 million benefit from the reversal of penalty expense on uncertain tax positions that were effectively settled. At December 31, 2021, Virginia Power had an income tax-related affiliated receivable of $35 million, comprised of $33 million of federal income taxes and $2 million of state income taxes receivable from Dominion Energy. These affiliated balances are expected to be received from Dominion Energy. At December 31, 2020, Virginia Power had an income tax-related affiliated payable of $19 million, comprised of $17 million of federal income taxes and $2 million of state income taxes due to Dominion Energy. Virginia Power’s net affiliated balances were paid to Dominion Energy. Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
Cash, Restricted Cash and Equivalents	Cash, Restricted Cash and Equivalents Cash, restricted cash and equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less. Current banking arrangements generally do not require checks to be funded until they are presented for payment. The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies: At December 2021 2020 (millions) Dominion Energy $ 70 $ 50 Virginia Power 15 30 Restricted Cash and Equivalents The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for litigation settlements, customer deposits, federal assistance funds and future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements (through December 2021), on DECP Holdings’ term loan agreement and on Eagle Solar’s senior note agreement. The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2021, 2020 and 2019: Cash, Restricted Cash and Equivalents at End/Beginning of Year December 31, 2021 December 31, 2020 December 31, 2019 December 31, 2018 (millions) Dominion Energy Cash and cash equivalents (1) $ 283 $ 179 $ 166 $ 268 Restricted cash and equivalents (2)(3) 125 68 103 123 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 408 $ 247 $ 269 $ 391 Virginia Power Cash and cash equivalents $ 26 $ 35 $ 17 $ 29 Restricted cash and equivalents (3) — — 7 9 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 26 $ 35 $ 24 $ 38 (1) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $7 million, $31 million and $110 million of cash and cash equivalents included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (2) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $3 million, $12 million and $89 million of restricted cash included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (3) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets. Supplemental Cash Flow Information The following table provides supplemental disclosure of cash flow information related to Dominion Energy: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 1,340 $ 1,519 $ 1,643 Income taxes 160 292 106 Significant noncash investing and financing activities: (1)(2)(3)(4)(5) Accrued capital expenditures 637 485 555 Leases (6) 96 173 157 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 3 for noncash investing and financing activities related to the SCANA Combination. (3) See Note 5 for noncash activities related to the sale of a noncontrolling interest in Cove Point. (4) See Note 9 for noncash investing activities related to the acquisition of a noncontrolling interest in Wrangler. (5) See Notes 18,19 and 20 for noncash financing activities related to the acquisition of the public interest in Dominion Energy Midstream, the remarketing of RSNs, the issuance of stock purchase contracts associated with the 2019 Equity Units, the contribution of stock to Dominion Energy’s qualified defined benefit pension plan, derivative restructuring and the issuance of common stock associated with the settlement of litigation. See Note 23 for non-cash investing activities related to property, plant and equipment conveyed to satisfy litigation. (6) Includes $47 million of finance leases and $49 million of operating leases entered in 2021, $46 million of finance leases and $127 million of operating leases entered in 2020 and $113 million of finance leases and $44 million of operating leases entered in 2019. The following table provides supplemental disclosure of cash flow information related to Virginia Power: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 501 $ 491 $ 495 Income taxes 109 452 272 Significant noncash investing activities: (1)(2) Accrued capital expenditures 363 262 292 Leases (3) 79 32 55 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 18 for non-cash financing activities related to derivative restructuring. (3) Includes $37 million of finance leases and $42 million of operating leases entered in 2021, $32 million of finance leases entered in, 2020 and $20 million of finance leases and $35 million of operating leases entered in 2019. Distributions from Equity Method Investees Dominion Energy holds investments that are accounted for under the equity method of accounting and classifies 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.
Derivative Instruments	Derivative Instruments The Companies are exposed to the impact of market fluctuations in the price of electricity, natural gas and other energy-related products they market and purchase, as well as interest rate and foreign currency exchange rate risks All derivatives, except those for which an exception applies, are required to be reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. The Companies do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion Energy had margin assets of $678 To manage price and interest rate risk, the Companies hold derivative instruments that are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices or interest rates . All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses, interest and related charges or discontinued operations based on the nature of the underlying risk. Changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings. Derivative Instruments Designated as Hedging Instruments In accordance with accounting guidance pertaining to derivatives and hedge accounting, the Companies designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For derivative instruments that are accounted for as cash flow hedges or fair value hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows. Cash Flow Hedges A majority of the Companies’ hedge strategies represents cash flow hedges of the variable price risk primarily associated with the use of interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which the Companies are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item, or as appropriate to regulatory assets or regulatory liabilities. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable. Fair Value Hedges Dominion Energy has also designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item’s fair value. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred. In 2021, 2020 and 2019, Dominion Energy capitalized interest costs and AFUDC to property, plant and equipment of $117 million, $103 million and $78 million, respectively. In 2021, 2020 and 2019, Virginia Power capitalized AFUDC to property, plant and equipment of $78 million, $60 million and $34 million, respectively. Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2021, 2020 and 2019, Virginia Power recorded $35 million, $11 million and $11 million of AFUDC related to these projects, respectively. For property subject to cost-of-service rate regulation, including the Companies’ electric distribution, electric transmission and generation property and Dominion Energy’s natural gas distribution property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be abandoned and recorded as a regulatory asset for amounts expected to be collected through future rates. In 2020 and 2019, the Companies had the following charges, primarily recorded in impairment of assets and other charges in the Consolidated Statements of Income (reflected in the Corporate and Other segment), related to early retirements: • In March 2020, Virginia Power committed to retire certain coal- and oil-fired generating units before the end of their useful lives based on economic and other factors, including but not limited to market power prices and the VCEA. These units will be retired after they meet their capacity obligations to PJM in 2023. As a result, Virginia Power recorded a charge of $ million ($ million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. In addition, see Note 13 for information on the settlement of the 2021 Triennial Review. Also in 2020, Virginia Power recorded charges of $ 54 million ($ 40 million after-tax) associated with dismantling certain of these electric generation facilities. • In January 2019, Virginia Power committed to a plan to retire certain automated metering reading infrastructure associated with its electric operations before the end of its estimated useful life and replace such equipment with more current AMI technology. As a result, Virginia Power recorded a charge of $160 million ($119 million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. • In March 2019, Virginia Power committed to retire certain electric generating units before the end of their useful lives and completed the retirement of certain units at six facilities representing 1,292 MW of electric generating capacity, which had previously been placed in cold reserve. An additional unit at Possum Point power station was retired after meeting its capacity obligation to PJM in December 2020. As a result, Virginia Power recorded a charge of $346 million ($257 million after-tax). This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13. In addition, see Note 13 for information on the settlement of the 2021 Triennial Review. • In May 2019, Virginia Power abandoned a coal rail project at its Mt. Storm generating facility. As a result, Virginia Power recorded a charge of $62 million ($46 million after-tax). • In September 2019, the Companies abandoned certain property, plant and equipment before the end of its useful life. As a result, Dominion Energy recorded a charge of $26 million ($19 million after-tax) and Virginia Power recorded a charge of $17 million ($12 million after-tax). For property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property’s net book value at the retirement date. Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. The Companies’ average composite depreciation rates on utility property, plant and equipment are as follows: Year Ended December 2021 2020 2019 (percent) Dominion Energy (1) Generation 2.63 2.51 2.84 Transmission 2.47 2.48 2.50 Distribution 2.76 2.76 2.80 Storage 1.79 1.59 1.49 General and other 3.85 4.35 3.99 Virginia Power Generation 2.69 2.52 2.94 Transmission 2.51 2.52 2.54 Distribution 3.18 3.19 3.14 General and other 5.08 5.09 4.40 (1) Excludes rates for depreciation reported as discontinued operations. In 2020, Virginia Power updated depreciation rates for its nuclear plants to reflect lower depreciation rates as a result of expected approval of license extensions from the NRC. For the year ended December 31, 2020, this adjustment resulted in a decrease of $31 million ($23 million after-tax) in depreciation expense in Virginia Power’s Consolidated Statements of Income and an increase to Dominion Energy’s EPS of $0.03 per share. In January 2022, Dominion Energy revised the estimated useful life of its non-jurisdictional and certain nonregulated solar generation facilities to 35 years. This revision is expected to result in an annual decrease of depreciation expense of approximately $20 million ($15 million after-tax), including approximately $8 million ($6 million after-tax) at Virginia Power, and increase Dominion Energy’s EPS by approximately $0.02. Virginia Power’s non-jurisdictional property, plant and equipment is depreciated using the straight-line method over an estimated useful life of 35 years, effective January 2022. Capitalized costs of development wells and leaseholds are amortized on a field-by-field basis using the unit-of-production method and the estimated proved developed or total proved gas and oil reserves, at a rate of $1.92 and $1.97 per mcfe in 2021 and 2020, respectively. Dominion Energy’s nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives: Asset Estimated Nonregulated generation-nuclear 44 years Nonregulated generation-solar 15-35 years General and other 5-59 years Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production basis. The Companies report the amortization of nuclear fuel in electric fuel and other energy-related purchases expense in their Consolidated Statements of Income and in depreciation and amortization in their Consolidated Statements of Cash Flows.
Long-Lived and Intangible Assets	Long-Lived and Intangible Assets The Companies perform an evaluation for impairment whenever events or changes in circumstances indicate that the carrying amount of long-lived assets or intangible assets with finite lives may not be recoverable. A long-lived or intangible asset is written down to fair value if the sum of its expected future undiscounted cash flows is less than its carrying amount. Intangible assets with finite lives are amortized over their estimated useful lives. See Note 6 for further discussion on the impairment of long-lived assets.
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities The accounting for the Companies’ regulated electric and gas operations differs from the accounting for nonregulated operations in that the Companies are required to reflect the effect of rate regulation in their Consolidated Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Likewise, regulatory liabilities are recognized when it is probable that regulators will require customer refunds or other benefits through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. The Companies evaluate whether or not recovery of their regulatory assets through future rates is probable as well as whether a regulatory liability due to customers is probable and make various assumptions in their analyses. These analyses are generally based on: • Orders issued by regulatory commissions, legislation and judicial actions; • Past experience; • Discussions with applicable regulatory authorities and legal counsel; • Forecasted earnings; and • Considerations around the likelihood of impacts from events such as unusual weather conditions, extreme weather events and other natural disasters and unplanned outages of facilities. Generally, regulatory assets and liabilities are amortized into income over the period authorized by the regulator. If recovery of a regulatory asset is determined to be less than probable, it will be written off in the period such assessment is made. A regulatory liability, if considered probable, will be recorded in the period such assessment is made or reversed into earnings if no longer probable. See Notes 12 and 13 to the Consolidated Financial Statements for additional information.
Leases	Leases The Companies lease certain assets including vehicles, real estate, office equipment and other operational assets under both operating and finance leases. For the Companies’ operating leases, rent expense is recognized on a straight-line basis over the term of the lease agreement, subject to regulatory framework. Rent expense associated with operating leases, short-term leases and variable leases is primarily recorded in other operations and maintenance expense in the Companies’ Consolidated Statements of Income. Rent expense associated with finance leases results in the separate presentation of interest expense on the lease liability and amortization expense of the related right-of-use asset in the Companies’ Consolidated Statements of Income or, subject to regulatory framework, is deferred within regulatory assets in the Consolidated Balance Sheets and amortized into the Consolidated Statements of Income. Certain of the Companies’ leases include one or more options to renew, with renewal terms that can extend the lease from one to 70 years. The exercise of renewal options is solely at the Companies’ discretion and is included in the lease term if the option is reasonably certain to be exercised. A right-of-use asset and corresponding lease liability for leases with original lease terms of one year or less are not included in the Consolidated Balance Sheets, unless such leases contain renewal options that the Companies are reasonably certain will be exercised. Additionally, certain of the Companies’ leases contain escalation clauses whereby payments are adjusted for consumer price or other indices or contain fixed dollar or percentage increases. The Companies also have leases with variable payments based upon usage of, or revenues associated with, the leased assets. The determination of the discount rate utilized has a significant impact on the calculation of the present value of the lease liability included in the Companies’ Consolidated Balance Sheets. For the Companies’ fleet of leased vehicles, the discount rate is equal to the prevailing borrowing rate earned by the lessor. For the Companies’ remaining leased assets, the discount rate implicit in the lease is generally unable to be determined from a lessee perspective. As such, the Companies use internally-developed incremental borrowing rates as a discount rate in the calculation of the present value of the lease liability. The incremental borrowing rates are determined based on an analysis of the Companies’ publicly available unsecured borrowing rates, adjusted for a collateral discount, over various lengths of time that most closely correspond to the Companies’ lease maturities. In addition, Dominion Energy acts as lessor under certain power purchase agreements in which the counterparty or counterparties purchase substantially all of the output of certain solar facilities. These leases are considered operating in nature. For such leasing arrangements, rental revenue and an associated accounts receivable are recorded when the monthly output of the solar facility is determined. Depreciation on these solar facilities is computed on a straight-line basis over an estimated useful life of 35 years, effective January 2022.
Asset Retirement Obligations	Asset Retirement Obligations The Companies recognize AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed, for which a legal obligation exists. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. Quarterly, the Companies assess their AROs to determine if circumstances indicate that estimates of the amounts or timing of future cash flows associated with retirement activities have changed. AROs are adjusted when significant changes in the amounts or timing of future cash flows are identified. Dominion Energy reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipelines of its distribution business as an adjustment to the related regulatory assets or liabilities when revenue is recoverable from customers for AROs. The Companies report accretion of AROs and depreciation on asset retirement costs associated with decommissioning its nuclear power stations as an adjustment to the regulatory asset or liability for certain jurisdictions. Additionally, the Companies report accretion of AROs and depreciation on asset retirement costs associated with certain rider and prospective rider projects and other electric generation and distribution facilities as an adjustment to the regulatory asset for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs are reported in other operations and maintenance expense and depreciation expense, respectively, in the Consolidated Statements of Income.
Debt Issuance Costs	Debt Issuance Costs The Companies defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. Deferred debt issuance costs are recorded as a reduction in long-term debt in the Consolidated Balance Sheets. Amortization of the issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt securities prior to stated maturity dates are generally recognized and recorded in interest expense immediately. As permitted by regulatory authorities, gains or losses resulting from the refinancing or redemption of debt allocable to utility operations subject to cost-based rate regulation are deferred and amortized.
Investments	Investments Debt Securities 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 credit-related impairments) on investments held in nuclear decommissioning trusts are deferred to a regulatory asset or liability, as applicable, for certain jurisdictions subject to cost-based regulation. For all other available-for-sale debt securities, including those held in Dominion Energy’s nonregulated generation nuclear decommissioning trusts, net realized gains and losses (including any credit-related 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. Credit Impairment The Companies periodically review their available-for-sale debt securities to determine whether a decline in fair value should be considered credit related. If a decline in the fair value of any available-for-sale debt security is determined to be credit related, the credit-related impairment is recorded to an allowance included in nuclear decommissioning trust funds in the Companies’ Consolidated Balance Sheets at the end of the reporting period, with such allowance for credit losses subject to reversal in subsequent evaluations. Using information obtained from their nuclear decommissioning trust fixed-income investment managers, the Companies record in earnings, or defer as applicable for certain jurisdictions subject to cost-based regulation, 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, the Companies record the credit loss in earnings or defer as applicable for certain jurisdictions subject to cost-based regulation, with the remaining non-credit portion of the unrealized loss recorded in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors Equity Securities with Readily Determinable Fair Values 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 the Companies in the nuclear decommissioning trusts. The Companies 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. Net realized and unrealized gains and losses on equity securities held in the nuclear decommissioning trusts are deferred to a regulatory asset or liability, as applicable, for certain jurisdictions subject to cost-based regulation. For all other equity securities, including those held in Dominion Energy’s nonregulated 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 in its Consolidated Balance Sheets, except for the liability to Atlantic Coast Pipeline or where such investments are classified as held for sale. Dominion Energy records equity method adjustments in other income in its Consolidated Statements of Income, including its 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 the Companies do not have the ability to exercise significant influence over the investee. The Companies’ 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 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 investment is written down to its fair value at the end of the reporting period.
Inventories	Inventories Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory is valued using the weighted-average cost method, except for East Ohio gas distribution operations, which are valued using the LIFO method. Under the LIFO method, current stored gas inventory was valued at $26 million and $2 million at December 31, 2021 and December 31, 2020, respectively. Based on the average price of gas purchased during 2021 and 2020, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by $74 million and $52 million, respectively.
Gas Imbalances	Gas Imbalances Natural gas imbalances occur when the physical amount of natural gas delivered from, or received by, a pipeline system or storage facility differs from the contractual amount of natural gas delivered or received. Dominion Energy values these imbalances due to, or from, shippers and operators at an appropriate index price at period end, subject to the terms of its tariff for regulated entities. Imbalances are primarily settled in-kind. Imbalances due to Dominion Energy from other parties are reported in other current assets and imbalances that Dominion Energy owes to other parties are reported in other current liabilities in the Consolidated Balance Sheets.
Goodwill	Goodwill Dominion Energy evaluates goodwill for impairment annually as of April 1 and whenever an event occurs or circumstances change in the interim that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount.
New Accounting Standards	New Accounting Standards Debt with Conversion Options and Contracts in an Entity’s Own Equity In August 2020, the FASB issued revised accounting guidance for debt with conversion options and contracts in an entity’s own equity. The revised guidance eliminates the ability to assert cash settlement and exclude potential shares from the diluted EPS calculation for a contract that may be settled in stock or cash. The guidance became effective for Dominion Energy’s interim and annual reporting periods beginning January 1, 2022. Upon adoption, Dominion Energy will apply the guidance using a modified retrospective approach and will continue to apply the if-converted method to calculate diluted EPS in connection with any potentially dilutive instruments, or components of instruments, that may be settled in stock or cash. Leases In February 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of leasing arrangements. The update requires that a liability and corresponding right-of-use asset are recorded on the balance sheet for all leases, including those leases classified as operating leases, while also refining the definition of a lease. In addition, lessees are required to disclose key information about the amount, timing and uncertainty of cash flows arising from leasing arrangements. Lessor accounting remains largely unchanged. The guidance became effective for the Companies’ interim and annual reporting periods beginning January 1, 2019. The Companies adopted this revised accounting guidance using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the date of adoption. The Companies applied the practical expedients, which required no reassessment of whether existing contracts are or contain leases, no reassessment of lease classification for existing leases and no reassessment of existing or expired land easements that were not previously accounted for as leases. In connection with the adoption of this revised accounting guidance, Dominion Energy and Virginia Power recorded $504 million and $209 million, respectively, of offsetting right-of-use assets and liabilities for operating leases in effect at the adoption date. Upon entering an agreement to sell substantially all of Dominion Energy’s gas transmission and storage operations in 2020, $43 million of the initially recorded right-of-use assets and liabilities for operating leases were considered activity associated with discontinued operations. See Note 15 for additional information.
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 and futures contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices and volumes. For Level 3 fair value measurements, certain forward market prices and implied price volatilities are considered unobservable.
Regulatory Matters Involving Potential Loss Contingencies	Regulatory Matters Involving Potential Loss Contingencies As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations.
Commitments and Contingencies	As a result of issues generated in the ordinary course of business, the Companies are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. The Companies maintain various insurance programs, including general liability insurance coverage which provides coverage for personal injury or wrongful death cases. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the Companies’ maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the Companies’ financial position, liquidity or results of operations.
Guarantees, Surety Bonds and Letters of Credit	Dominion Energy also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion Energy would be obligated to satisfy such obligation. To the extent that a liability subject to a guarantee has been incurred by one of Dominion Energy’s consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion Energy is not required to recognize liabilities for guarantees issued on behalf of its subsidiaries unless it becomes probable that it will have to perform under the guarantees. Terms of the guarantees typically end once obligations have been paid. Dominion Energy currently believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries’ obligations.

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Schedule of Checks Outstanding but Not Yet Presented for Payment	The following table illustrates the checks outstanding but not yet presented for payment and recorded in accounts payable for the Companies: At December 2021 2020 (millions) Dominion Energy $ 70 $ 50 Virginia Power 15 30
Reconciliation of Total Cash, Restricted Cash and Equivalents	The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the years ended December 31, 2021, 2020 and 2019: Cash, Restricted Cash and Equivalents at End/Beginning of Year December 31, 2021 December 31, 2020 December 31, 2019 December 31, 2018 (millions) Dominion Energy Cash and cash equivalents (1) $ 283 $ 179 $ 166 $ 268 Restricted cash and equivalents (2)(3) 125 68 103 123 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 408 $ 247 $ 269 $ 391 Virginia Power Cash and cash equivalents $ 26 $ 35 $ 17 $ 29 Restricted cash and equivalents (3) — — 7 9 Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows $ 26 $ 35 $ 24 $ 38 (1) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $7 million, $31 million and $110 million of cash and cash equivalents included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (2) At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $3 million, $12 million and $89 million of restricted cash included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021. (3) Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.
Schedule of Supplemental Cash Flow Information	The following table provides supplemental disclosure of cash flow information related to Dominion Energy: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 1,340 $ 1,519 $ 1,643 Income taxes 160 292 106 Significant noncash investing and financing activities: (1)(2)(3)(4)(5) Accrued capital expenditures 637 485 555 Leases (6) 96 173 157 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 3 for noncash investing and financing activities related to the SCANA Combination. (3) See Note 5 for noncash activities related to the sale of a noncontrolling interest in Cove Point. (4) See Note 9 for noncash investing activities related to the acquisition of a noncontrolling interest in Wrangler. (5) See Notes 18,19 and 20 for noncash financing activities related to the acquisition of the public interest in Dominion Energy Midstream, the remarketing of RSNs, the issuance of stock purchase contracts associated with the 2019 Equity Units, the contribution of stock to Dominion Energy’s qualified defined benefit pension plan, derivative restructuring and the issuance of common stock associated with the settlement of litigation. See Note 23 for non-cash investing activities related to property, plant and equipment conveyed to satisfy litigation. (6) Includes $47 million of finance leases and $49 million of operating leases entered in 2021, $46 million of finance leases and $127 million of operating leases entered in 2020 and $113 million of finance leases and $44 million of operating leases entered in 2019. The following table provides supplemental disclosure of cash flow information related to Virginia Power: Year Ended December 31, 2021 2020 2019 Cash paid during the year for: Interest and related charges, excluding capitalized amounts $ 501 $ 491 $ 495 Income taxes 109 452 272 Significant noncash investing activities: (1)(2) Accrued capital expenditures 363 262 292 Leases (3) 79 32 55 (1) See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements. (2) See Note 18 for non-cash financing activities related to derivative restructuring. (3) Includes $37 million of finance leases and $42 million of operating leases entered in 2021, $32 million of finance leases entered in, 2020 and $20 million of finance leases and $35 million of operating leases entered in 2019.
Schedule of Depreciation Rates	The Companies’ average composite depreciation rates on utility property, plant and equipment are as follows: Year Ended December 2021 2020 2019 (percent) Dominion Energy (1) Generation 2.63 2.51 2.84 Transmission 2.47 2.48 2.50 Distribution 2.76 2.76 2.80 Storage 1.79 1.59 1.49 General and other 3.85 4.35 3.99 Virginia Power Generation 2.69 2.52 2.94 Transmission 2.51 2.52 2.54 Distribution 3.18 3.19 3.14 General and other 5.08 5.09 4.40 (1) Excludes rates for depreciation reported as discontinued operations.
Property, Plant and Equipment	Dominion Energy’s nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives: Asset Estimated Nonregulated generation-nuclear 44 years Nonregulated generation-solar 15-35 years General and other 5-59 years

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2021
SCANA
Schedule of Allocation of Purchase Price to Assets Acquired and Liabilities Assumed	The table below shows the allocation of the purchase price to the assets acquired and liabilities assumed at closing, which reflects certain adjustments related to income taxes, as discussed in Note 5, from the preliminary valuation recognized during the measurement period. Amount (millions) Total current assets (1) $ 1,782 Investments (2) 224 Property, plant and equipment (3)(4) 11,006 Goodwill 2,609 Regulatory assets (5) 3,940 Other deferred charges and other assets, including intangible assets (6) 430 Total Assets 19,991 Total current liabilities (7) 1,556 Long-term debt 6,707 Deferred income taxes 1,068 Regulatory liabilities 2,706 Other deferred credits and other liabilities (8) 1,115 Total Liabilities 13,152 Total purchase price (9) $ 6,839 (1) Includes $389 million of cash, restricted cash and equivalents, of which $115 million is considered restricted. (2) Includes $31 million for equity method investments. The fair value adjustment on the equity method investments is considered to be equity method goodwill and is not amortized. (3) Includes $105 million of certain property, plant and equipment associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. As a result, Dominion Energy’s Consolidated Statements of Income for the year ended December 31, 2019 include a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges (reflected in the Corporate and Other segment). (4) Nonregulated property, plant and equipment, excluding land, will be depreciated on a straight-line basis over the remaining useful lives of such property, primarily ranging from 5 to 78 years. (5) Includes $258 million of certain income tax-related regulatory assets associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. See Note 5 for additional information. (6) Intangible assets have an estimated weighted-average amortization period of approximately five years. (7) Includes $40 million outstanding under letters of credit advances, which were repaid in January 2019, as well as $173 million outstanding commercial paper under various credit facilities. All such credit facilities were terminated in 2019. (8) Includes a $379 million pension and other postretirement benefit liability. (9) Includes stock-based compensation awards with a fair value of $21 million.
Business Acquisition, Pro Forma Information	The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of the combined company. Twelve Months Ended December 31, 2019 (1) (millions, except EPS) Operating revenue $ 15,408 Net income attributable to Dominion Energy 3,266 Earnings Per Common Share – $ 4.04 Earnings Per Common Share – $ 4.00 (1) Amounts include adjustments for non-recurring costs directly related to the SCANA Combination.
GT&S Transaction | Dominion Energy Gas Holdings, LLC
Results of Operations Reported within Discontinued Operations	The following table represents selected information regarding the results of operations, which are reported within discontinued operations in Dominion Energy’s Consolidated Statements of Income: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 Q-Pipe Group (1) GT&S Transaction (1) Q-Pipe Group GT&S Transaction Q-Pipe Group (millions) Operating revenue $ 254 $ 1,710 $ 246 $ 2,213 $ 251 Operating expense (2) 76 1,289 96 1,367 131 Other income (loss) (3) 28 88 1 58 4 Interest and related charges (4) 25 372 20 267 20 Income before income taxes 181 137 131 637 104 Income tax expense (benefit) (5) 36 334 (9 ) 120 23 Net income (loss) including noncontrolling interests 145 (197 ) 140 517 81 Noncontrolling interests — 106 — 11 — Net income (loss) attributable to Dominion Energy $ 145 $ (303 ) $ 140 $ 506 $ 81 (1) Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date. (2) GT&S Transaction includes a charge of $482 million ($359 million after-tax) recorded in the second quarter of 2020 associated with the probable abandonment of a significant portion of the Supply Header Project as well as the establishment of a $75 million ARO as a result of the cancellation of the Atlantic Coast Pipeline Project. ( 3 ) Q-Pipe Group includes a $25 million benefit associated with the termination of the Q-Pipe Transaction in the third quarter of 2021. (4) GT&S Transaction includes a loss of $237 million ($178 million after-tax) recorded in the third quarter of 2020 associated with cash flow hedges of debt-related items that were determined to be probable of not occurring. (5) Excludes $17 million income tax benefit recorded in 2021 associated with the GT&S Transaction.
Schedule of Major Classes of Assets and Liabilities Reported As Held for Sale in Discontinued Operations	The carrying amounts of major classes of assets and liabilities relating to the Q-Pipe Group, all of which was classified as current and reported as held for sale in Dominion Energy’s Consolidated Balance Sheets at December 31, 2020, were as follows: (millions) Current assets (1) $ 47 Equity method investments (2) 35 Property, plant and equipment, net 1,113 Other deferred charges and other assets, including goodwill (3) 224 Current liabilities 30 Long-term debt 426 Other deferred credits and liabilities 154 (1) Includes cash and cash equivalents of $7 million. ( 2 ) Comprised of equity method investment in White River Hub. ( 3 ) Includes goodwill of $191 million.
Capital Expenditures and Significant Noncash Items Relating to the Disposal Groups	Capital expenditures and significant noncash items relating to the disposal groups included the following: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 Q-Pipe Group (1) GT&S Transaction (1) Q-Pipe Group GT&S Transaction Q-Pipe Group (millions) Capital expenditures $ 34 $ 292 $ 38 $ 386 $ 42 Significant noncash items Impairment of assets and other charges — 469 — 13 1 Charge related to a voluntary retirement program — — — 19 3 Depreciation, depletion and amortization — 177 27 322 51 Accrued capital expenditures — — 1 25 2 (1) Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date.

Operating Revenue (Tables)

Operating Revenue (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated And Unregulated Operating Revenue [Abstract]
Schedule of Operating Revenue	The Companies’ operating revenue consists of the following: Year Ended December 31, 2021 2020 2019 (millions) Dominion Energy Regulated electric sales: Residential $ 4,509 $ 4,833 $ 4,325 Commercial 3,194 3,102 3,219 Industrial 748 730 683 Government and other retail 921 868 873 Wholesale 175 128 176 Nonregulated electric sales 1,005 823 941 Regulated gas sales: Residential 1,455 1,283 1,343 Commercial 527 457 457 Other 135 88 109 Nonregulated gas sales 96 174 495 Regulated gas transportation and storage 945 801 742 Other regulated revenues 265 327 252 Other nonregulated revenues (1)(2) 195 138 130 Total operating revenue from contracts with customers 14,170 13,752 13,745 Other revenues (3)(4) (206 ) 420 656 Total operating revenue $ 13,964 $ 14,172 $ 14,401 Virginia Power Regulated electric sales: Residential $ 3,366 $ 3,677 $ 3,657 Commercial 2,417 2,342 2,712 Industrial 367 380 455 Government and other retail 862 804 823 Wholesale 107 90 128 Nonregulated electric sales 44 19 15 Other regulated revenues 234 299 190 Other nonregulated revenues (1)(2) 73 50 56 Total operating revenue from contracts with customers 7,470 7,661 8,036 Other revenues (1)(3) — 102 72 Total operating revenue $ 7,470 $ 7,763 $ 8,108 (1) See Notes 9 and 25 for amounts attributable to related parties and affiliates. (2) Includes sales which are considered to be goods transferred at a point (3) Includes alternative revenue of $56 million, $119 million and $66 million at Dominion Energy and $44 million, $82 million and $52 million at Virginia Power for years ended December 31, 2021, 2020 and 2019, respectively. (4) Includes revenue associated with services provided to discontinued operations of $5 million, $4 million and $6 million for the years ended December 31, 2021, 2020 and 2019, respectively.
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 Dominion Energy expects to recognize this revenue. These revenues relate to contracts containing fixed prices where Dominion Energy will earn the associated revenue over time as it stands 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 Dominion Energy elects to recognize revenue in the amount it has a right to invoice. Revenue expected to be recognized on multi-year contracts in place at December 31, 2021 2022 2023 2024 2025 2026 Thereafter Total (millions) Dominion Energy (1) $ 68 $ 66 $ 59 $ 51 $ 45 $ 448 $ 737 (1) Includes no amounts for Virginia Power.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income tax expense for continuing operations including noncontrolling interests	Details of income tax expense for continuing operations including noncontrolling interests were as follows: Dominion Energy Virginia Power Year Ended December 2021 2020 2019 2021 2020 2019 (millions) Current: Federal $ (162 ) $ (314 ) $ (94 ) $ 67 $ 364 $ 286 State 45 (81 ) 58 (13 ) 71 58 Total current expense (benefit) (117 ) (395 ) (36 ) 54 435 344 Deferred: Federal Taxes before operating loss carryforwards, investment tax credits and tax reform 151 12 168 145 (226 ) (128 ) Tax utilization expense of operating loss carryforwards 43 44 119 — — — Investment tax credits 250 311 (51 ) (39 ) (27 ) (34 ) State (19 ) 72 (50 ) 118 7 22 Total deferred expense (benefit) 425 439 186 224 (246 ) (140 ) Investment tax credit-gross deferral 121 42 62 121 42 62 Investment tax credit-amortization (4 ) (3 ) (3 ) (2 ) (2 ) (2 ) Total income tax expense $ 425 $ 83 $ 209 $ 397 $ 229 $ 264
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 Year Ended December 2021 2020 2019 2021 2020 2019 U.S. statutory rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increases (reductions) resulting from: State taxes, net of federal benefit 2.6 2.0 1.5 4.6 4.8 4.5 Investment tax credits (3.2 ) (9.6 ) (11.4 ) (3.0 ) (4.5 ) (2.9 ) Production tax credits (0.4 ) (0.7 ) (2.1 ) (0.6 ) (0.7 ) (0.7 ) Valuation allowances 0.1 0.9 0.5 — — — Reversal of excess deferred income taxes (3.2 ) (5.4 ) (3.2 ) (2.1 ) (2.2 ) (3.1 ) State legislative change (0.7 ) — — (0.7 ) — — Write-off of regulatory assets — — 21.7 — — — Change in tax status — (1.7 ) (5.5 ) — — — AFUDC—equity (0.4 ) (0.2 ) (0.2 ) (0.5 ) — — Changes in state deferred taxes associated with assets held for sale (0.3 ) (3.2 ) — — — — Absence of tax on noncontrolling interest (0.1 ) 3.8 (0.2 ) — — — Settlements of uncertain tax positions (1.2 ) — — — — — Employee stock ownership plan deduction (0.3 ) (0.9 ) (1.4 ) — — — Nondeductible goodwill — — 1.8 — — — Other, net (0.2 ) (0.1 ) 1.5 0.1 (0.1 ) (0.2 ) Effective tax rate 13.7 % 5.9 % 24.0 % 18.8 % 18.3 % 18.6 %
Deferred income taxes components	The Companies’ deferred income taxes consist of the following: Dominion Energy Virginia Power At December 2021 2020 2021 2020 (millions) Deferred income taxes: Total deferred income tax assets $ 3,025 $ 3,285 $ 1,373 $ 1,204 Total deferred income tax liabilities 9,397 9,069 4,286 3,832 Total net deferred income tax liabilities $ 6,372 $ 5,784 $ 2,913 $ 2,628 Total deferred income taxes: Plant and equipment, primarily depreciation method and basis differences $ 6,017 $ 5,824 $ 3,327 $ 3,227 Excess deferred income taxes (1,107 ) (1,142 ) (629 ) (656 ) Unrecovered NND Project costs 508 529 — — DESC rate refund (113 ) (140 ) — — Toshiba Settlement (189 ) (204 ) — — Nuclear decommissioning 1,114 991 324 303 Deferred state income taxes 857 702 420 305 Federal benefit of deferred state income taxes (179 ) (147 ) (88 ) (64 ) Deferred fuel, purchased energy and gas costs 189 (28 ) 126 (34 ) Pension benefits 362 239 (119 ) (105 ) Other postretirement benefits 73 (14 ) 93 76 Loss and credit carryforwards (1,571 ) (1,534 ) (537 ) (354 ) Valuation allowances 140 155 6 6 Partnership basis differences 398 593 — — Other (127 ) (40 ) (10 ) (76 ) Total net deferred income tax liabilities $ 6,372 $ 5,784 $ 2,913 $ 2,628 Deferred Investment Tax Credits – 286 169 270 151 Total Deferred Taxes and Deferred Investment Tax Credits $ 6,658 $ 5,953 $ 3,183 $ 2,779
Summary of deductible loss and credit carryforwards	At December 31, 2021, Dominion Energy had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration Amount Tax Asset Allowance Period (millions) Federal losses $ 965 $ 203 $ — 2037 Federal investment credits — 752 — 2036-2041 Federal production and other credits — 63 — 2036-2041 State losses 4,583 243 (50 ) 2022-2041 State minimum tax credits — 214 — No expiration State investment and other credits — 129 (90 ) 2022-2031 Total $ 5,548 $ 1,604 $ (140 ) At December 31, 2021, Virginia Power had the following deductible loss and credit carryforwards: Deductible Deferred Valuation Expiration Amount Tax Asset Allowance Period (millions) Federal losses $ — $ — $ — Federal investment credits — 467 — 2036-2041 Federal production and other credits — 62 — 2036-2041 State investment and other credits — 8 (6 ) 2024 Total $ — $ 537 $ (6 )
Reconciliation of changes in unrecognized tax benefits	A reconciliation of changes in the Companies’ unrecognized tax benefits follows: Dominion Energy Virginia Power 2021 2020 2019 2021 2020 2019 (millions) Balance at January 1 $ 167 $ 175 $ 44 $ — $ — $ 2 Acquired unrecognized tax benefits — — 129 (1 ) — — — Increases-prior period positions 48 18 — — — — Decreases-prior period positions (59 ) (19 ) — — — — Increases-current period positions 2 1 9 — — — Settlements with tax authorities (26 ) — (7 ) — — (2 ) Expiration of statutes of limitations (4 ) (8 ) — — — — Balance at December 31 $ 128 $ 167 $ 175 $ - $ — $ - (1) Acquired unrecognized tax benefits reflect $106 million plus increases in prior period positions of $76 million and decreases in prior period positions of $53 million that were recorded through purchase accounting.
Earliest tax year remaining	For each of the major states in which Dominion Energy operates, the earliest tax year remaining open for examination is as follows: Earliest Open Tax State Year Pennsylvania (1) 2012 Connecticut 2018 Virginia (2) 2018 Utah 2018 South Carolina 2018 (1) Considered a major state for entities presented in discontinued operations. (2) Considered a major state for Virginia Power’s operations

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Inputs, Assets, Quantitative Information	The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at December 31, 2021. 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: Natural gas (2) $ 54 Discounted cash flow Market price (per Dth) (3) (2)-8 (1 ) FTRs 51 Discounted cash flow Market price (per MWh) (3) (2)-11 2 Electricity 120 Discounted cash flow Market price (per MWh) (3) 28-72 43 Physical options: Natural gas 5 Option model Market price (per Dth) (3) 3-9 6 Price volatility (4) 19% - 27% 24 % Total assets $ 230 Liabilities Physical and financial forwards: Natural gas (2) $ 3 Discounted cash flow Market price (per Dth) (3) (2)-4 (1 ) FTRs 5 Discounted cash flow Market price (per MWh) (3) (3)-7 1 Total liabilities $ 8 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents 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) December 31, 2021 Assets Derivatives: Commodity $ — $ 52 $ 230 $ 282 Interest rate — 323 — 323 Foreign currency exchange rate — 8 — 8 Investments (1) Equity securities: U.S. 5,241 — — 5,241 Fixed income: Corporate debt instruments — 881 — 881 Government securities 199 1,256 — 1,455 Cash equivalents and other (29 ) — — (29 ) Total assets $ 5,411 $ 2,520 $ 230 $ 8,161 Liabilities Derivatives: Commodity $ — $ 461 $ 8 $ 469 Interest rate — 399 — 399 Total liabilities $ — $ 860 $ 8 $ 868 December 31, 2020 Assets Derivatives: Commodity $ — $ 57 $ 110 $ 167 Interest rate — 230 — 230 Investments (1) Equity securities: U.S. 4,648 — — 4,648 Fixed income: Corporate debt instruments — 629 — 629 Government securities 508 730 — 1,238 Cash equivalents and other 32 15 — 47 Total assets $ 5,188 $ 1,661 $ 110 $ 6,959 Liabilities Derivatives: Commodity $ — $ 48 $ 7 $ 55 Interest rate — 431 — 431 Total liabilities $ — $ 479 $ 7 $ 486 (1) Includes investments held in the nuclear decommissioning trusts and rabbi trusts. Excludes $366 million and $340 million of assets at December 31, 2021 and 2020, 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: 2021 2020 2019 (millions) Balance at January 1, $ 103 $ (37 ) $ 64 Total realized and unrealized gains (losses): Included in earnings: Operating Revenue (9 ) — (1 ) Electric fuel and other energy-related purchases 10 (33 ) (22 ) Purchased gas — — 2 Discontinued operations — 1 — Included in regulatory assets/liabilities 119 140 (90 ) Settlements (10 ) 33 17 Purchases — — (10 ) Sales — (1 ) 6 Transfers out of Level 3 9 — (3 ) Balance at December 31, $ 222 $ 103 $ (37 )
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: December 31, 2021 2020 Carrying Amount Estimated Fair Value (1) Carrying Amount Estimated Fair Value (1) (millions) Dominion Energy Long-term debt (2)(3) $ 35,996 $ 40,947 $ 31,996 $ 38,773 Supplemental 364-Day credit facility borrowings — — 225 225 Junior subordinated notes (4) 1,386 1,470 3,411 3,633 Virginia Power Long-term debt (4) $ 13,753 $ 16,021 $ 13,207 $ 16,455 (1) Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value. (2) Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs and discount or premium. At December 31, 2021 and December 31, 2020, the carrying amount includes the valuation of certain fair value hedges associated with fixed rate debt of $2 million and $3 million, respectively. (3) Includes amounts classified as held for sale at December 31, 2020, see Note 3. ( 4 ) Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs, discount or premium.
Virginia Electric and Power Company
Fair Value Inputs, Assets, Quantitative Information	The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at December 31, 2021. 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: Natural gas (2) $ 54 Discounted cash flow Market price (per Dth) (3) (2)-6 (1 ) FTRs 51 Discounted cash flow Market price (per MWh) (3) (2)-11 2 Physical options: Natural gas 5 Option model Market price (per Dth) (3) 3-9 6 Price volatility (4) 19% - 27% 24 % Total assets $ 110 Liabilities Physical and financial forwards: Natural gas (2) $ 3 Discounted cash flow Market price (per Dth) (3) (2)-4 (1 ) FTRs 5 Discounted cash flow Market price (per MWh) (3) (3)-7 1 Total liabilities $ 8 (1) Averages weighted by volume. (2) Includes basis. (3) Represents market prices beyond defined terms for Levels 1 and 2. (4) Represents 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) December 31, 2021 Assets Derivatives: Commodity $ — $ 36 $ 110 $ 146 Interest rate — 146 — 146 Foreign currency exchange rate — 8 — 8 Investments (1) Equity securities: U.S. 2,420 — — 2,420 Fixed income: Corporate debt instruments — 531 — 531 Government securities 93 506 — 599 Cash equivalents and other (3 ) — — (3 ) Total assets $ 2,510 $ 1,227 $ 110 $ 3,847 Liabilities Derivatives: Commodity $ — $ 125 $ 8 $ 133 Interest rate — 337 — 337 Total liabilities $ — $ 462 $ 8 $ 470 December 31, 2020 Assets Derivatives: Commodity $ — $ 5 $ 110 $ 115 Interest rate — 66 — 66 Investments (1) Equity securities: U.S. 2,171 — — 2,171 Fixed income: Corporate debt instruments — 348 — 348 Government securities 201 309 — 510 Cash equivalents and other 13 — — 13 Total assets $ 2,385 $ 728 $ 110 $ 3,223 Liabilities Derivatives: Commodity $ — $ 22 $ 7 $ 29 Interest rate — 376 — 376 Total liabilities $ — $ 398 $ 7 $ 405 (1) Includes investments held in the nuclear decommissioning trusts. Excludes $185 million and $167 million of assets at December 31, 2021 and 2020, 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: 2021 2020 2019 (millions) Balance at January 1, $ 103 $ (37 ) $ 60 Total realized and unrealized gains (losses): Included in earnings: Electric fuel and other energy-related purchases 4 (33 ) (22 ) Included in regulatory assets/liabilities (1 ) 140 (88 ) Settlements (4 ) 33 13 Balance at December 31, $ 102 $ 103 $ (37 )

Derivatives and Hedge Account_2

Derivatives and Hedge Accounting Activities (Tables)	12 Months Ended
	Dec. 31, 2021
Offsetting Assets	The tables below present Dominion Energy’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 153 $ 13 $ — $ 140 $ 117 $ 9 $ — $ 108 Exchange 9 7 — 2 49 24 — 25 Interest rate contracts: Over-the-counter 323 49 — 274 230 13 — 217 Foreign currency exchange rate contracts: Over-the-counter 8 — — 8 — — — — Total derivatives, subject to a master netting or similar arrangement $ 493 $ 69 $ — $ 424 $ 396 $ 46 $ — $ 350 (1) Excludes $120 million and $1 million of derivative assets at December 31, 2021 and 2020, respectively,
Offsetting Liabilities	December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities Presented in the Consolidated Balance Sheet Financial Instruments Cash Collateral Paid Net Amounts Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 95 $ 13 $ 54 $ 28 $ 30 $ 9 $ — $ 21 Exchange 374 7 367 — 24 24 — — Interest rate contracts: Over-the-counter 399 49 11 339 431 13 17 401 Total derivatives, subject to a master netting or similar arrangement $ 868 $ 69 $ 432 $ 367 $ 485 $ 46 $ 17 $ 422 (1) Excludes $1 million of derivative liabilities at December 31, 2020
Schedule of Volume of Derivative Activity	The following table presents the volume of Dominion Energy’s derivative activity as of December 31, 2021. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 34 5 Basis 156 446 Electricity (MWh in millions): Fixed price 15 31 FTRs 44 — Interest rate (2) $ 1,537 $ 9,859 Foreign currency exchange rate (2) 501 kr. 4,581 kr. (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 Dominion Energy’s Consolidated Balance Sheets at December 31, 2021: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (358 ) $ (40 ) 396 months Total $ (358 ) $ (40 )
Schedule of Amounts Recorded on Balance Sheet Related to Cumulative Basis Adjustments for Fair Value Hedges	The following table presents the amounts recorded on the Consolidated Balance Sheets related to cumulative basis adjustments for fair value hedges all of which related to discontinued hedging relationships at both December 31, 2021 and 2020, respectively: Carrying Amount of the Hedged Asset (Liability) Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets (Liabilities) December 31, 2021 December 31, 2020 December 31, 2021 December 31, 2020 (millions) Long-term debt $ (352 ) $ (1,153 ) $ (2 ) $ (3 )
Fair Value of Derivatives	Fair Value and Gains and Losses on Derivative Instruments The following tables present the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2021 ASSETS Current Assets Commodity $ — $ 103 $ 103 Interest rate 1 17 18 Foreign currency exchange rate — 1 1 Total current derivative assets (1) 1 121 122 Noncurrent Assets Commodity — 179 179 Interest rate 145 160 305 Foreign currency exchange rate — 7 7 Total noncurrent derivative assets (2) 145 346 491 Total derivative assets $ 146 $ 467 $ 613 LIABILITIES Current Liabilities Commodity $ — $ 304 $ 304 Interest rate 42 13 55 Total current derivative liabilities (3) 42 317 359 Noncurrent Liabilities Commodity — 165 165 Interest rate 295 49 344 Total noncurrent derivative liabilities (4) 295 214 509 Total derivative liabilities $ 337 $ 531 $ 868 At December 31, 2020 ASSETS Current Assets Commodity $ — $ 58 $ 58 Interest rate — 9 9 Total current derivative assets (1) — 67 67 Noncurrent Assets Commodity — 109 109 Interest rate 66 155 221 Total noncurrent derivative assets (2) 66 264 330 Total derivative assets $ 66 $ 331 $ 397 LIABILITIES Current Liabilities Commodity $ — $ 42 $ 42 Interest rate 363 10 373 Total current derivative liabilities (3) 363 52 415 Noncurrent Liabilities Commodity — 13 13 Interest rate 19 39 58 Total noncurrent derivative liabilities (4) 19 52 71 Total derivative liabilities $ 382 $ 104 $ 486 (1) At December 31, 2021, all current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $63 million is included in other current assets and the remainder is recorded in current assets held for sale. (2) A t December 31, 2021, all noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets . At December 31, 2020, $ 330 million is included in other deferred charges and other assets and the remainder is recorded in noncurrent assets held for sale. (3) At December 31, 2021, all current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $412 million is included in other current liabilities and the remainder is recorded in current liabilities held for sale. (4) At December 31, 2021, all noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $71 million is included in other deferred credits and other liabilities and the remainder is recorded in noncurrent liabilities held for sale.
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 (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2021 Derivative type and location of gains (losses): Commodity (3) $ (1 ) Interest rate (4) $ 21 (60 ) $ 135 Total $ 21 $ (61 ) $ 135 Year Ended December 31, 2020 Derivative type and location of gains (losses): Commodity: Operating revenue $ 25 Purchased gas (4 ) Discontinued operations 2 Total commodity $ — $ 23 $ — Interest rate: Interest and related charges $ (83 ) Discontinued operations (236 ) Total interest rate $ (309 ) $ (319 ) $ (332 ) Foreign currency exchange rate (5) (11 ) (6 ) — Total $ (320 ) $ (302 ) $ (332 ) Year Ended December 31, 2019 Derivative type and location of gains (losses): Commodity: Operating revenue $ 142 Purchased gas (3 ) Discontinued operations 4 Total commodity $ 125 $ 143 $ — Interest rate: Interest and related charges $ (49 ) Discontinued operations (5 ) Total interest rate $ (252 ) $ (54 ) $ (255 ) Foreign currency exchange rate (5) (18 ) (6 ) — Total $ (145 ) $ 83 $ (255 ) (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 purchased gas. (4) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges. ( 5 ) Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in discontinued operations.
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) Year Ended December 31, 2021 2020 2019 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (487 ) $ 73 $ 41 Purchased gas (1 ) (20 ) (22 ) Electric fuel and other energy-related purchases 16 (104 ) (46 ) Discontinued operations — (11 ) (2 ) Interest rate: Interest and related charges 97 87 3 Discontinued operations — 5 — Foreign currency exchange rate: Discontinued operations — 12 — Total $ (375 ) $ 42 $ (26 ) (1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion Energy’s Consolidated Statements of Income.
Virginia Electric and Power Company
Offsetting Assets	The tables below present Virginia Power’s derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid: December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts Gross Assets Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Received Net Amounts (millions) Commodity contracts: Over-the-counter $ 110 $ 8 $ — $ 102 $ 111 $ 6 $ — $ 105 Exchange 7 7 — — 1 1 — — Interest rate contracts: Over-the-counter 146 20 — 126 66 7 — 59 Foreign currency exchange rate contracts: Over-the-counter 8 — — 8 — — — — Total derivatives, subject to a master netting or similar arrangement $ 271 $ 35 $ — $ 236 $ 178 $ 14 $ — $ 164 (1) Excludes $29 million and $3 million of derivative assets at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements.
Offsetting Liabilities	December 31, 2021 December 31, 2020 Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Amounts Not Offset in the Consolidated Balance Sheet Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts Gross Liabilities Presented in the Consolidated Balance Sheet (1) Financial Instruments Cash Collateral Paid Net Amounts (millions) Commodity contracts: Over-the-counter $ 84 $ 8 $ 54 $ 22 $ 6 $ 6 $ — $ — Exchange 43 7 36 — 1 1 — — Interest rate contracts: Over-the-counter 337 20 — 317 376 7 — 369 Total derivatives, subject to a master netting or similar arrangement $ 464 $ 35 $ 90 $ 339 $ 383 $ 14 $ — $ 369 (1) Excludes $6 million and $22 million of derivative liabilities at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements.
Schedule of Volume of Derivative Activity	The following table presents the volume of Virginia Power’s derivative activity at December 31, 2021. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. Current Noncurrent Natural Gas (bcf): Fixed price (1) 24 5 Basis 139 440 Electricity (MWh in millions): Fixed price 6 7 FTRs 44 — Interest rate (2) $ 1,000 $ 1,750 Foreign currency exchange rate (2) 501 kr. 4,581 kr. (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 Sheets at December 31, 2021: AOCI After-Tax Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax Maximum Term (millions) Interest rate $ (45 ) $ (2 ) 396 months Total $ (45 ) $ (2 )
Fair Value of Derivatives	The following tables present the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets: Fair Value – Derivatives under Hedge Accounting Fair Value – Derivatives not under Hedge Accounting Total Fair Value (millions) At December 31, 2021 ASSETS Current Assets Commodity $ — $ 74 $ 74 Interest rate 1 — 1 Foreign currency exchange rate — 1 1 Total current derivative assets (1) 1 75 76 Noncurrent Assets Commodity — 72 72 Interest rate 145 — 145 Foreign currency exchange rate — 7 7 Total noncurrent derivative assets (2) 145 79 224 Total derivative assets $ 146 $ 154 $ 300 LIABILITIES Current Liabilities Commodity $ — $ 92 $ 92 Interest rate 42 — 42 Total current derivative liabilities 42 92 134 Noncurrent Liabilities Commodity — 41 41 Interest rate 295 — 295 Total noncurrent derivatives liabilities (3) 295 41 336 Total derivative liabilities $ 337 $ 133 $ 470 At December 31, 2020 ASSETS Current Assets Commodity $ — $ 22 $ 22 Total current derivative assets (1) — 22 22 Noncurrent Assets Commodity — 93 93 Interest rate 66 — 66 Total noncurrent derivative assets (2) 66 93 159 Total derivative assets $ 66 $ 115 $ 181 LIABILITIES Current Liabilities Commodity $ — $ 28 $ 28 Interest rate 362 — 362 Total current derivative liabilities 362 28 390 Noncurrent Liabilities Commodity — 1 1 Interest rate 14 — 14 Total noncurrent derivatives liabilities (3) 14 1 15 Total derivative liabilities $ 376 $ 29 $ 405 (1) Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets. (2) Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets. (3) Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.
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 (1) Amount of Gain (Loss) Reclassified From AOCI to Income Increase (Decrease) in Derivatives Subject to Regulatory Treatment (2) (millions) Year Ended December 31, 2021 Derivative type and location of gains (losses): Interest rate (3) $ 17 $ (3 ) $ 130 Total $ 17 $ (3 ) $ 130 Year Ended December 31, 2020 Derivative type and location of gains (losses): Interest rate (3) $ (37 ) $ (2 ) $ (338 ) Total $ (37 ) $ (2 ) $ (338 ) Year Ended December 31, 2019 Derivative type and location of gains (losses): Interest rate (3) $ (30 ) $ (1 ) $ (259 ) Total $ (30 ) $ (1 ) $ (259 ) (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) Year Ended December 31, 2021 2020 2019 (millions) Derivative type and location of gains (losses): Commodity: Operating revenue $ (62 ) $ (104 ) $ (45 ) Electric fuel and other energy-related purchases 9 — — Total $ (53 ) $ (104 ) $ (45 ) (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.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Earnings Per Share Computation	The following table presents the calculation of Dominion Energy’s basic and diluted EPS: 2021 2020 2019 (millions, except EPS) Net income attributable to Dominion Energy from continuing operations $ 2,647 $ 1,583 $ 653 Preferred stock dividends (see Note 19) (68 ) (65 ) (17 ) Net income attributable to Dominion Energy from continuing operations - Basic 2,579 1,518 636 Dilutive effect of Series A Preferred Stock — (11 ) (28 ) Net income attributable to Dominion Energy from continuing operations - Diluted 2,579 $ 1,507 $ 608 Net income (loss) attributable to Dominion Energy from discontinued operations - Basic & Diluted 641 $ (1,984 ) $ 705 Average shares of common stock outstanding – Basic 807.8 831.0 808.8 Net effect of dilutive securities (1) 0.7 — 0.1 Average shares of common stock outstanding – Diluted 808.5 831.0 808.9 EPS from continuing operations - Basic $ 3.19 $ 1.83 $ 0.79 EPS from discontinued operations - Basic 0.79 (2.39 ) 0.87 EPS attributable to Dominion Energy - Basic $ 3.98 $ (0.56 ) $ 1.66 EPS from continuing operations - Diluted 3.19 $ 1.82 $ 0.75 EPS from discontinued operations - Diluted 0.79 (2.39 ) 0.87 EPS attributable to Dominion Energy - Diluted $ 3.98 $ (0.57 ) $ 1.62 (1) Dilutive securities for 2021 consist primarily of stock expected to be issued to satisfy the obligation under a settlement agreement with the SCDOR (applying the if converted method) as well as forward sales agreements entered into in November 2021 (applying the treasury stock method). See Notes 20 and 23 for additional information.

Investments (Tables)

Investments (Tables)	12 Months Ended
	Dec. 31, 2021
Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds	Dominion Energy’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Allowance for Credit Losses Fair Value (millions) December 31, 2021 Equity securities: (1) U.S. $ 1,567 $ 3,734 $ (13 ) $ 5,288 Fixed income securities: (2) Corporate debt instruments 854 32 (5 ) $ — 881 Government securities 1,382 43 (7 ) — 1,418 Common/collective trust funds 168 4 — — 172 Insurance contracts 255 — — 255 Cash equivalents and other (3) 9 2 (75 ) — (64 ) Total $ 4,235 $ 3,815 $ (100 ) (4) $ — $ 7,950 December 31, 2020 Equity securities: (1) U.S. $ 1,756 $ 2,948 $ (24 ) $ 4,680 Fixed income securities: (2) Corporate debt instruments 572 58 (1 ) $ — 629 Government securities 1,119 66 (1 ) — 1,184 Common/collective trust funds 170 5 — — 175 Insurance contracts 237 — — 237 Cash equivalents and other (3) (8 ) 4 (1 ) — (5 ) Total $ 3,846 $ 3,081 $ (27 ) (4) $ — $ 6,900 (1) Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2. (2) Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. Changes in allowance for credit losses are included in other income. (3) Includes pending purchases of securities of $35 million and $49 million at December 31, 2021 and 2020, respectively. (4) The fair value of securities in an unrealized loss position was $883 million and $293 million at December 31, 2021 and 2020, respectively.
Unrealized Gain Loss on Equity	The portion of unrealized gains and losses that relates to equity securities held within Dominion Energy’s nuclear decommissioning trusts is summarized below: Year Ended December 31, 2021 2020 2019 (millions) Net gains (losses) recognized during the period $ 1,072 $ 512 $ 919 Less: Net gains recognized during the period on securities sold during the period (346 ) (16 ) (80 ) Unrealized gains (losses) recognized during the period on securities still held at period end (1) $ 726 $ 496 $ 839 (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 fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2021 by contractual maturity is as follows: Amount (millions) Due in one year or less $ 331 Due after one year through five years 642 Due after five years through ten years 630 Due after ten years 868 Total $ 2,471
Marketable Securities	Presented below is selected information regarding Dominion Energy’s equity and fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2021 2020 2019 (millions) Proceeds from sales $ 3,985 $ 4,278 $ 1,712 Realized gains (1) 441 340 195 Realized losses (1) 91 297 96 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.
Investments Accounts Under Equity Method of Accounting	Investments that Dominion Energy accounts for under the equity method of accounting are as follows: Investment Company Ownership% Balance Description As of December 2021 2020 (millions) Cove Point 50 % $ 2,738 $ 2,784 LNG import/export and storage facility Atlantic Coast Pipeline 53 % — (3) — (3) Gas transmission system Wrangler 15 % (2) 68 74 Nonregulated retail energy marketing Align RNG (1) 50 % 74 25 Renewable natural gas Other various 52 51 Total $ 2,932 $ 2,934 (1) Dominion Energy’s unfunded commitment to be made to Align RNG by the end of 2022 was $8 million and $59 million at December 31, 2021 and 2020, respectively. The commitment was fully paid in January 2022. (2) Dominion Energy’s ownership interest became 15% in December 2021, following the sale of 5% of its ownership interest. See discussion below. (3) Dominion Energy’s Consolidated Balance Sheets include a liability associated with its investment in Atlantic Coast Pipeline of $113 million and $1.1 billion at December 31, 2021 and 2020, respectively. See discussion below for additional information.
Virginia Electric and Power Company
Equity and Debt Securities and Cash Equivalents and Cost Method Investments in Decommissioning Trust Funds	Virginia Power’s decommissioning trust funds are summarized below: Amortized Cost Total Unrealized Gains Total Unrealized Losses Allowance for Credit Losses Fair Value (millions) December 31, 2021 Equity securities: (1) U.S. $ 841 $ 1,720 $ (11 ) $ 2,550 Fixed income securities: (2) Corporate debt instruments 517 17 (3 ) $ — 531 Government securities 584 16 (2 ) — 598 Common/collective trust funds 53 — — — 53 Cash equivalents and other (3) 2 — — — 2 Total $ 1,997 $ 1,753 $ (16 ) (4) $ — $ 3,734 December 31, 2020 Equity securities: (1) U.S. $ 929 $ 1,371 $ (21 ) $ 2,279 Fixed income securities: (2) Corporate debt instruments 315 33 — $ — 348 Government securities 484 25 — — 509 Common/collective trust funds 58 — — — 58 Cash equivalents and other (3) 3 — — — 3 Total $ 1,789 $ 1,429 $ (21 ) (4) $ — $ 3,197 (1) Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2 (2) Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. Changes in allowance for credit losses are included in other income. (3) Includes pending sales of securities of $5 million at December 31, 2021, and pending purchases of securities of $10 million at December 31, 2020. (4) The fair value of securities in an unrealized loss position was $425 million and $142 million at December 31, 2021 and 2020, respectively.
Unrealized Gain Loss on Equity	The portion of unrealized gains and losses that relates to equity securities held within Virginia Power’s nuclear decommissioning trusts is summarized below: Year Ended December 31, 2021 2020 2019 (millions) Net gains (losses) recognized during the period $ 552 $ 224 $ 423 Less: Net gains recognized during the period on securities sold during the period (190 ) (6 ) (20 ) Unrealized gains (losses) recognized during the period on securities still held at end of period (1) $ 362 $ 218 $ 403 (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 fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at December 31, 2021, by contractual maturity is as follows: Amount (millions) Due in one year or less $ 78 Due after one year through five years 335 Due after five years through ten years 361 Due after ten years 408 Total $ 1,182
Marketable Securities	Presented below is selected information regarding Virginia Power’s equity and fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds. Year Ended December 31, 2021 2020 2019 (millions) Proceeds from sales $ 1,791 $ 884 $ 858 Realized gains (1) 228 88 58 Realized losses (1) 35 68 22 (1) Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Property Plant And Equipment (T

Property Plant And Equipment (Tables)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment	Major classes of property, plant and equipment and their respective balances for the Companies are as follows: At December 31, 2021 2020 (millions) Dominion Energy Utility: Generation $ 23,378 $ 22,697 Transmission 15,430 14,351 Distribution 28,953 27,311 Storage 455 436 Nuclear fuel 2,306 2,283 General and other 4,373 4,130 Plant under construction 3,898 3,350 Total utility 78,793 74,558 Non-jurisdictional - including plant under construction 1,694 1,225 Nonutility: Nonregulated generation-nuclear 1,773 1,736 Nonregulated generation-solar 2,026 3,268 Nuclear fuel 1,056 1,012 Other-including plant under construction 1,161 1,160 Total nonutility 6,016 7,176 Total property, plant and equipment $ 86,503 $ 82,959 Virginia Power Utility: Generation $ 17,325 $ 16,769 Transmission 11,760 11,000 Distribution 13,621 12,839 Nuclear fuel 1,702 1,709 General and other 912 845 Plant under construction 2,865 2,338 Total utility 48,185 45,500 Non-jurisdictional - including plant under construction 1,694 1,225 Other 11 11 Total property, plant and equipment $ 49,890 $ 46,736
Schedule of Jointly Owned Utility Plants	The Companies proportionate share of jointly-owned power stations at December 31, 2021 is as follows: Bath County Pumped Storage Station (1) North Anna Units 1 and 2 (1) Clover Power Station (1) Millstone Unit 3 (2) Summer Unit 1 (2) (millions, except percentages) Ownership interest 60 % 88.4 % 50 % 93.5 % 66.7 % Plant in service 1,063 2,532 610 1,353 1,522 Accumulated depreciation (714 ) (1,381 ) (273 ) (522 ) (699 ) Nuclear fuel — 730 — 549 603 Accumulated amortization of nuclear fuel — (576 ) — (406 ) (387 ) Plant under construction 6 178 1 127 76 (1) Units jointly owned by Virginia Power. (2) Unit jointly owned by Dominion Energy.
Virginia Electric and Power Company
Schedule of Business Acquisitions, by Acquisition	The following table presents acquisitions by Virginia Power of solar projects. Virginia Power has claimed or expects to claim federal investment tax credits on the projects. Project Name Date Agreement Entered Date Agreement Closed Project Location Project Cost (millions (1)] Date of Commercial Operations MW Capacity Gutenberg September 2017 June 2019 North Carolina 142 September 2019 80 Gloucester June 2018 February 2019 Virginia 37 April 2019 20 Grasshopper (2) August 2018 May 2019 Virginia 128 October 2020 80 Chestnut August 2018 May 2019 North Carolina 127 January 2020 75 Ft. Powhatan June 2019 June 2019 Virginia 267 January 2022 150 Belcher (3) June 2019 August 2019 Virginia 164 June 2021 88 Bedford August 2019 November 2019 Virginia 106 November 2021 70 Maplewood October 2019 October 2019 Virginia 185 Expected 2022 120 Rochambeau December 2019 January 2020 Virginia 35 December 2021 20 Pumpkinseed May 2020 May 2020 Virginia 130 Expected 2022 60 Bookers Mill February 2021 June 2021 Virginia 200 Expected 2023 127 (1) Includes acquisition costs. (2) Referred to as Butcher Creek once placed in service. (3) Referred to as Desper once placed in service.
Dominion Energy
Schedule of Business Acquisitions, by Acquisition	The following table presents acquisitions by Dominion Energy of solar projects in addition to the Virginia Power solar projects presented above. Dominion Energy has claimed or expects to claim federal investment tax credits on the projects. Project Name Date Agreement Entered Date Agreement Closed Project Location Project Cost (millions) (1) Date of Commercial Operations MW Capacity Greensville August 2019 August 2019 Virginia $ 127 December 2020 80 Myrtle August 2019 August 2019 Virginia 32 June 2020 15 Seabrook September 2019 September 2019 South Carolina 103 December 2019 72 Wilkinson November 2019 November 2019 North Carolina 153 December 2019 74 Blackville May 2020 May 2020 South Carolina 12 December 2020 7 Denmark May 2020 May 2020 South Carolina 14 December 2020 6 Yemassee May 2020 August 2020 South Carolina 17 January 2021 10 Trask May 2020 October 2020 South Carolina 22 March 2021 12 Hardin I June 2020 June 2020 Ohio 240 Split (2) 150 Madison July 2020 July 2020 Virginia 125 Expected 2023 62 Hardin II August 2020 Expected 2022 Ohio 295 Expected 2023 150 (1) Includes acquisition costs. (2)

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2021
Goodwill And Intangible Assets Disclosure [Abstract]
Segment allocation of goodwill	The changes in Dominion Energy’s carrying amount and segment allocation of goodwill are presented below: Dominion Energy Virginia Gas Distribution Dominion Energy South Carolina Contracted Assets Corporate and Other Total (millions) Dominion Energy Balance at December 31, 2019 (1) $ 2,106 $ 3,512 $ 1,521 $ 242 $ 14 $ 7,395 Contribution to Wrangler (2) — — — — (14 ) (14 ) Balance at December 31, 2020 (1) $ 2,106 $ 3,512 $ 1,521 $ 242 $ — $ 7,381 Acquisition of Birdseye (3) — — — 24 — 24 Balance at December 31, 2021 (1) $ 2,106 $ 3,512 $ 1,521 $ 266 $ — $ 7,405 (1) Goodwill amounts do not contain any accumulated impairment losses. (2) See Note 9 for additional information including amounts reclassified to held for sale at December 31, 2020. (3) See Note 3 for more information.
Components of intangible assets	The components of intangible assets are as follows: 2021 2020 At December 31, Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization (millions) Dominion Energy Software, licenses and other (1) $ 1,459 $ 675 $ 1,295 $ 530 Virginia Power Software, licenses and other (1) $ 685 $ 290 $ 482 $ 148 (1) Includes $158M of RGGI allowances purchased
Annual amortization expense of intangible assets	Annual amortization expense for these intangible assets is estimated to be as follows: 2022 2023 2024 2025 2026 (millions) Dominion Energy $ 72 $ 58 $ 50 $ 42 $ 28 Virginia Power $ 29 $ 23 $ 20 $ 16 $ 9

Regulatory Assets and Liabili_2

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Schedule of Regulatory Assets and Liabilities	Regulatory assets and liabilities include the following: At December 31, 2021 2020 (millions) Dominion Energy Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 251 $ — Deferred project costs and DSM programs for gas utilities (2) 53 35 Unrecovered gas costs (3) 191 78 Deferred rider costs for Virginia electric utility (4) 72 98 Ashpond and landfill closure costs (5) 193 — Deferred nuclear refueling outage costs (6) 79 53 NND Project costs (7) 138 138 PJM transmission rates (8) 7 71 Deferred early plant retirement charges (9) 226 — Derivatives (10) 112 33 Other 170 193 Regulatory assets-current 1,492 699 Unrecognized pension and other postretirement benefit costs (11) 548 1,363 Deferred rider costs for Virginia electric utility (4) 489 311 Deferred project costs for gas utilities (2) 675 632 Interest rate hedges (12) 899 1,042 AROs and related funding (13) 329 331 Cost of reacquired debt (14) 10 245 NND Project costs (7) 2,226 2,364 Ash pond and landfill closure costs (5) 2,223 2,301 Deferred cost of fuel used in electric generation (1) 409 — Deferred early plant retirement charges (9) 226 — Other 609 544 Regulatory assets-noncurrent 8,643 9,133 Total regulatory assets $ 10,135 $ 9,832 Regulatory liabilities: Deferred cost of fuel used in electric generation (1) $ — $ 58 Provision for future cost of removal and AROs (15) 181 183 Reserve for refunds and rate credits to electric utility customers (16) 420 128 Reserve for future credits to Virginia electric customers (17) — 120 Income taxes refundable through future rates (18) 153 124 Monetization of guarantee settlement (19) 67 67 Commodity derivatives (10) 55 9 Other 110 120 Regulatory liabilities-current 986 809 Income taxes refundable through future rates (18) 4,260 4,376 Provision for future cost of removal and AROs (15) 2,331 2,150 Nuclear decommissioning trust (20) 2,158 1,719 Monetization of guarantee settlement (19) 831 903 Reserve for refunds and rate credits to electric utility customers (16) 448 540 Unrecognized pension and other postretirement benefit costs ( 1 1) 200 66 Overrecovered other postretirement benefit costs (2 1 ) 105 111 Other 380 322 Regulatory liabilities-noncurrent 10,713 10,187 Total regulatory liabilities $ 11,699 $ 10,996 (1) Reflects deferred fuel expenses for the Virginia, North Carolina and South Carolina jurisdictions of Dominion Energy’s electric generation operations. (2) Primarily reflects amounts expected to be collected from or owed to gas customers in Dominion Energy’s service territories associated with current and prospective rider projects, including CEP, PIR and pipeline integrity management. See Note 13 for more information . (3) Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority (4) Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information (5) Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on (6) 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. (7) Reflects expenditures by DESC associated with the NND Project, which pursuant to the SCANA Merger Approval Order, will be recovered from DESC electric service customers over a 20-year period ending in 2039. See Note 3 for more information (8) Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter.‌ (9) Reflects amounts from the early retirements of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for additional information (10) 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 (11) 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 rate-regulated subsidiaries (12) Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 27 years as of December 31, 2021 (13) Represents deferred depreciation and accretion expense related to legal obligations associated with the future retirement of generation, transmission and distribution properties. The AROs primarily relate to DESC’s electric generating facilities, including Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately 105 years (14) In 2021, DESC recorded a charge of $237 million ($178 million after-tax) in impairment of assets and other charges, reflected in the Corporate and Other segment, to write-off the balance of a regulatory asset that is no longer probable of recovery under the settlement agreement approved in DESC’s retail electric base rate case. (15) Rates charged to customers by Dominion Energy’s 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 (16) Reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period effective February 2019, in connection with the SCANA Merger Approval Order. See Notes 3 and 13 for more information (17) Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information. (18) Amounts recorded to pass the effect of reduced income taxes from the 2017 Tax Reform Act to customers in future periods, which will primarily 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 (19) Reflects amounts to be refunded to DESC electric service customers over a 20-year period ending in 2039 associated with the monetization of a bankruptcy settlement agreement. See Note 3 for more information. (20) 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, as applicable) for the future decommissioning of Dominion Energy’s utility nuclear generation stations, in excess of the related AROs. (21) Reflects a regulatory liability for the collection of postretirement benefit costs allowed in rates in excess of expense incurred. At December 31, 2021 2020 (millions) Virginia Power Regulatory assets: Deferred cost of fuel used in electric generation (1) $ 131 $ — Deferred rider costs (2) 72 98 Ash pond and landfill closure costs (3) 193 — Deferred nuclear refueling outage costs (4) 79 53 PJM transmission rates (5) 7 71 Deferred early plant retirement charges (6) 226 — Derivatives (7) 105 40 Other 37 33 Regulatory assets-current 850 295 Deferred rider costs (2) 489 311 Interest rate hedges (8) 604 733 Ash pond and landfill closure costs (3) 2,223 2,301 Deferred cost of fuel used in electric generation (1) 409 — Deferred early plant retirement charges (6) 226 — Other 179 164 Regulatory assets-noncurrent 4,130 3,509 Total regulatory assets $ 4,980 $ 3,804 Regulatory liabilities: Deferred cost of fuel used in electric generation (1) $ — $ 58 Provision for future cost of removal (9) 154 152 Reserve for refunds to Virginia electric customers (10) 306 — Reserve for future credits to Virginia electric customers (11) — 120 Income taxes refundable through future rates (12) 63 54 Derivatives (7) 51 8 Other 73 33 Regulatory liabilities-current 647 425 Income taxes refundable through future rates (12) 2,335 2,404 Nuclear decommissioning trust (13) 2,158 1,719 Provision for future cost of removal (9) 1,043 980 Deferred cost of fuel used in electric generation (1) — 54 Reserve for refunds to Virginia electric customers (10) 25 — Other 179 181 Regulatory liabilities-noncurrent 5,740 5,338 Total regulatory liabilities $ 6,387 $ 5,763 (1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s generation operations (2) Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information (3) Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on uncollected expenditures once expenditures have been made. See Note 13 for additional information. (4) 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 (5) Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter. (6) Reflects amounts from the early retirement of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for more information (7) For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers (8) Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 25 years as of December (9) Rates charged to customers by Virginia Power's regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement (10) Reflects amounts to be refunded to jurisdictional retail electric customers in Virginia associated with the settlement of the 2021 Triennial Review. See Note 13 for additional information (11) Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information (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

Regulatory Matters (Tables)

Regulatory Matters (Tables) - Virginia Electric and Power Company	12 Months Ended
	Dec. 31, 2021
Public Utilities General Disclosures [Line Items]
Summary of Additional Significant Riders Associated with Virginia Power Projects	Rider Name Application Date Approval Date Rate Year Beginning Total Revenue Requirement (millions) Increase (Decrease) Over Previous Year (millions) Rider B June 2020 February 2021 April 2021 24 (8 ) Rider B June 2021 February 2022 April 2022 16 (8 ) Rider BW October 2020 July 2021 September 2021 113 14 Rider BW October 2021 Pending September 2022 145 32 Rider BW October 2021 Pending September 2023 120 (25 ) Rider CCR February 2021 October 2021 December 2021 216 N/A Rider CE (1) October 2020 April 2021 June 2021 10 N/A Rider CE (2) September 2021 Pending May 2022 71 61 Rider E January 2021 September 2021 November 2021 67 (18 ) Rider E January 2022 Pending November 2022 101 34 Rider GT August 2021 Pending June 2022 56 N/A Rider GV June 2020 February 2021 April 2021 153 21 Rider GV June 2021 December 2021 April 2022 142 (11 ) Rider GV June 2021 December 2021 April 2023 127 (15 ) Rider OSW November 2021 Pending September 2022 79 N/A Rider R June 2020 February 2021 April 2021 58 14 Rider R June 2021 Pending April 2022 59 1 Rider R June 2021 Pending April 2023 55 (4 ) Rider RGGI (3) December 2020 August 2021 September 2021 168 N/A Rider RGGI (4) December 2021 Withdrawal pending Rider RPS December 2020 July 2021 August 2021 13 N/A Rider RPS December 2021 Pending September 2022 140 127 Rider S June 2020 February 2021 April 2021 194 (1 ) Rider S June 2021 February 2022 April 2022 192 (2 ) Rider S June 2021 February 2022 April 2023 191 (1 ) Rider SNA (5) October 2021 Pending September 2022 109 N/A Rider T1 (6) May 2021 August 2021 September 2021 874 (190 ) Rider U (7) June 2020 February 2021 April 2021 80 28 Rider U (8) June 2021 Pending April 2022 96 16 Rider US-2 October 2020 July 2021 September 2021 9 — Rider US-2 October 2021 Pending September 2022 11 2 Rider US-3 July 2020 March 2021 June 2021 38 10 Rider US-3 August 2021 Pending June 2022 50 12 Rider US-4 July 2020 March 2021 June 2021 10 3 Rider US-4 August 2021 Pending June 2022 15 5 Rider W June 2020 February 2021 April 2021 120 14 Rider W June 2021 February 2022 April 2022 121 1 DSM Riders (9) December 2020 September 2021 October 2021 74 14 DSM Riders (10) December 2021 Pending September 2022 91 17
Summary of Additional Significant Virginia Power Electric Transmission Projects Approved and Applied	Electric Transmission Projects Significant Virginia Power electric transmission projects approved or applied for are as follows: Description and Location of Project Application Date Approval Date Type of Line Miles of Lines Cost Estimate (millions) Bristers-Ladysmith Rebuild Project in the Counties of Fauquier, Stafford, Spotsylvania and Caroline, Virginia May 2020 February 2021 500 kV 37 110 Relocate and replace a transmission line underground between the Tysons substation and the future Spring Hill substation September 2020 June 2021 230 kV < 1 30 Rebuild an existing transmission line and install new line adjacent thereto in the Counties of New Kent, King William, King and Queen, Essex and Richmond, Virginia October 2020 December 2021 230 kV 41 100 Rebuild Clubhouse-Dry Bread Line and Dry Bread-Lakeview Line in Greensville County, Virginia November 2020 July 2021 230 kV 13 20 Rebuild transmission lines and related projects in the Counties of York and James City and the City of Williamsburg, Virginia January 2021 September 2021 230 kV 11 30 Elmont-Ladysmith rebuild and related projects in the Counties of Hanover and Caroline, Virginia April 2021 Pending 500 kV 26 95 Beaumeade-Belmont reconductor and rebuild projects in the County of Loudoun, Virginia May 2021 February 2022 230 kV 7 15 Extension to Cloud Switching Station and Easters Switching Station in the County of Mecklenburg, Virginia June 2021 February 2022 230 kV 15 105 Rebuild transmission lines and related projects in the City of Staunton and County of Augusta, Virginia November 2021 Pending 230 kV 21 45 Build new DTC substation and line loop in the County of Loudoun, Virginia December 2021 Pending 230 kV 1 105 Build new Aviator substation and line loop in the County of Loudoun, Virginia February 2022 Pending 230 kV 1 80

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Changes to Asset Retirement Obligations	The changes to AROs during 2020 and 2021 were as follows: Amount (millions) Dominion Energy AROs at December 31, 2019 $ 5,184 Obligations incurred during the period 67 Obligations settled during the period (114 ) Revisions in estimated cash flows (1) 228 Accretion 218 AROs at December 31, 2020 (2) $ 5,583 Obligations incurred during the period 31 Obligations settled during the period (165 ) Revisions in estimated cash flows (3) (151 ) Accretion 224 Sale of non-wholly-owned nonregulated solar facilities (49 ) AROs at December 31, 2021 (2) $ 5,473 Virginia Power AROs at December 31, 2019 $ 3,581 Obligations incurred during the period 48 Obligations settled during the period (85 ) Revisions in estimated cash flows ( 4 ) 139 Accretion 137 AROs at December $ 3,820 Obligations incurred during the period 26 Obligations settled during the period (131 ) Revisions in estimated cash flows ( 5 ) 67 Accretion 141 AROs at December $ 3,923 (1) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, asbestos abatement costs associated with certain utility facilities and from the completion of a nuclear decommissioning cost study related to Summer. ( 2 ) Includes $179 million and $198 million reported in other current liabilities at December 31, 2020 and 2021, respectively. (3) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, estimated cash flow projections associated with the recovery of spent nuclear fuel costs for its AROs associated with the decommissioning of Kewaunee and estimated cash flow projections associated with certain gas distribution pipelines. These revisions in 2021 resulted in a charge of $44 million ($35 million after-tax) within other operations and maintenance expense in the Consolidated Statements of Income as well as a $173 million decrease to property, plant and equipment, net. ( 4 ) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities and asbestos abatement costs associated with certain utility facilities. (5) Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities. In addition, Virginia Power revised its estimated cash flows for the existing ARO related to future ash pond and landfill closure costs, which resulted in a $113 million ($84 million after-tax) benefit in other operations and maintenance expense in the Consolidated Statements of Income in 2019.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Lease Assets and Liabilities Recorded in Consolidated Balance Sheets	At December 31, 2021 and 2020, the Companies had the following lease assets and liabilities recorded in the Consolidated Balance Sheets: December 31, 2021 December 31, 2020 (millions) Dominion Energy Lease assets: Operating lease assets (1) $ 506 $ 564 Finance lease assets (2) 144 148 Total lease assets $ 650 $ 712 Lease liabilities: Operating lease liabilities (3) $ 44 $ 54 Finance lease liabilities (4) 36 32 Total lease liabilities - current 80 86 Operating lease liabilities (5) 464 516 Finance lease liabilities (6) 112 108 Total lease liabilities - noncurrent 576 624 Total lease liabilities $ 656 $ 710 Virginia Power Operating lease assets (1) $ 256 $ 185 Finance lease assets (2) 71 45 Total lease assets $ 327 $ 230 Lease liabilities: Operating lease liabilities (3) $ 25 $ 28 Finance lease liabilities (4) 13 8 Total lease liabilities - current 38 36 Operating lease liabilities (5) 227 155 Finance lease liabilities (6) 57 36 Total lease liabilities - noncurrent 284 191 Total lease liabilities $ 322 $ 227 (1) Included in other deferred charges and other assets in the Companies’ Consolidated Balance Sheets. (2) Included in property, plant and equipment in the Companies’ Consolidated Balance Sheets, net of $81 million and $18 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2021 and net of $50 million and $9 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2020. (3) Included in other current liabilities in the Companies’ Consolidated Balance Sheets. (4) Included in securities due within one year in the Companies’ Consolidated Balance Sheets. (5) Included in other deferred credits and other liabilities in the Companies’ Consolidated Balance Sheets. (6) Included in other long-term debt in the Companies’ Consolidated Balance Sheets.
Summary of Total Lease Cost	For the years ended December 31, 2021, 2020 and 2019, total lease cost associated with the Companies’ leasing arrangements consisted of the following: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 (millions) Dominion Energy Finance lease cost: Amortization $ 40 $ 33 $ 20 Interest (3 ) — 4 Operating lease cost 66 68 79 Short-term lease cost 32 20 26 Variable lease cost 5 8 5 Total lease cost $ 140 $ 129 $ 134 Virginia Power Finance lease cost: Amortization $ 12 $ 7 $ 3 Interest 1 1 — Operating lease cost $ 30 $ 36 $ 41 Short-term lease cost 19 12 13 Variable lease cost 1 4 2 Total lease cost $ 63 $ 60 $ 59
Cash Paid for Amounts Included in Measurement of Lease Liabilities	For the years ended December 31, 2021, 2020 and 2019, cash paid for amounts included in the measurement of the lease liabilities consisted of the following amounts, included in the Companies’ Consolidated Statements of Cash Flows: Year Ended December 31, 2021 Year Ended December 31, 2020 Year Ended December 31, 2019 (millions) Dominion Energy Operating cash flows for finance leases $ (3 ) $ — $ 4 Operating cash flows for operating leases 103 96 111 Financing cash flows for finance leases 40 33 20 Virginia Power Operating cash flows for finance leases $ 1 $ 1 $ — Operating cash flows for operating leases 53 52 56 Financing cash flows for finance leases 12 7 3
Weighted Average Remaining Lease Term and Weighted Discounted Rate for Finance and Operating Leases	At December 31, 2021 and 2020, the weighted average remaining lease term and weighted discount rate for the Companies’ finance and operating leases were as follows: December 31, 2021 December 31, 2020 Dominion Energy Weighted average remaining lease term - finance leases 5 years 5 years Weighted average remaining lease term - operating leases 27 years 26 years Weighted average discount rate - finance leases 2.77 % 3.17 % Weighted average discount rate - operating leases 3.96 % 4.07 % Virginia Power Weighted average remaining lease term - finance leases 6 years 6 years Weighted average remaining lease term - operating leases 25 years 21 years Weighted average discount rate - finance leases 2.27 % 2.51 % Weighted average discount rate - operating leases 4.00 % 4.26 %
Scheduled Maturities of Lease Liabilities	The Companies’ lease liabilities have the following maturities: Maturity of Lease Liabilities Dominion Energy Virginia Power (millions) Operating Finance Operating Finance 2022 $ 50 $ 32 $ 27 $ 8 2023 41 39 21 14 2024 33 33 17 14 2025 27 18 13 13 2026 24 15 10 10 After 2026 577 22 240 17 Total undiscounted lease payments 752 159 328 76 Present value adjustment (244 ) (11 ) (76 ) (6 ) Present value of lease liabilities $ 508 $ 148 $ 252 $ 70

Short Term Debt and Credit Ag_2

Short Term Debt and Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Instrument [Line Items]
Schedule of Line of Credit Facilities	Dominion Energy’s short-term financing is supported through its access to the joint revolving credit facility described below. Commercial paper and letters of credit outstanding, as well as capacity available under the credit facility were as follows: Facility Limit Outstanding Commercial Paper (1) Outstanding Letters of Credit Facility Capacity Available (millions) At December 31, 2021 Joint revolving credit facility (2) $ 6,000 $ 1,883 $ 131 $ 3,986 At December 31, 2020 Joint revolving credit facility (2) $ 6,000 $ 627 $ 100 $ 5,273 (1) The weighted-average interest rates of the outstanding commercial paper supported by Dominion Energy’s credit facility was 0.31% and 0.29% at December 31, 2021 and 2020, respectively. (2) This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility 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	Virginia Power’s share of commercial paper and letters of credit outstanding under the joint revolving credit facility with Dominion Energy, Questar Gas and DESC were as follows: Facility Limit Outstanding Commercial Paper (1) Outstanding Letters of Credit (millions) At December 31, 2021 Joint revolving credit facility (2) $ 6,000 $ 745 $ 40 At December 31, 2020 Joint revolving credit facility (2) $ 6,000 $ 45 $ 12 (1) The weighted-average interest rates of the outstanding commercial paper supported by the credit facility was 0.26% and 0.30% at December 31, 2021 and 2020, respectively. (2) The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Questar Gas and DESC. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At December 31, 2021, the sub-limit for Virginia Power was $1.75 billion. If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion Energy. This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028. The credit facility 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.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Long term Debt	At December 31, 2021 Weighted- average Coupon (1) 2021 2020 (millions, except percentages) Virginia Electric and Power Company: Unsecured Senior Notes: 2.30% to 8.875%, due 2022 to 2051 4.07 % $ 13,238 $ 12,689 Tax-Exempt Financings (2) 0.45% to 1.90%, due 2032 to 2041 1.14 % 625 625 Virginia Electric and Power Company total principal $ 13,863 $ 13,314 Securities due within one year 3.45 % (300 ) — Unamortized discount, premium and debt issuances costs, net (110 ) (107 ) Derivative restructuring 446 444 Finance leases 57 36 Virginia Electric and Power Company total long-term debt $ 13,956 $ 13,687 Dominion Energy, Inc.: Supplemental 364-Day credit facility, variable rate, due 2021 $ — $ 225 Sustainability Revolving Credit Agreement, variable rate, due 2024 (3) — — Unsecured Senior Notes: Variable rate, due 2023 0.73 % 1,000 1,000 1.45% to 7.0%, due 2021 to 2049 (4) 3.78 % 11,238 9,938 Unsecured Junior Subordinated Notes: 2.715% to 4.104%, due 2021 and 2024 3.07 % 700 1,950 Payable to Affiliated Trust, 8.4%, due 2031 8.40 % 10 10 Enhanced Junior Subordinated Notes: 5.25% and 5.75%, due 2054 and 2076 (5) 5.75 % 685 1,485 DECP Holdings, Term Loan, variable rate, due 2024 (6) 1.50 % 2,500 — Questar Gas, Unsecured Senior Notes, 2.21% to 7.20%, due 2024 to 2051 3.85 % 1,000 750 East Ohio, Unsecured Senior Notes, 1.30% to 3.00%, due 2025 to 2050 2.25 % 1,800 1,800 PSNC, Senior Debentures and Notes, 3.10% to 7.45%, due 2021 to 2051 4.34 % 800 800 DESC: First Mortgage Bonds, 2.30% to 6.625%, due 2021 to 2065 5.09 % 3,634 3,267 Tax-Exempt Financings (7) Variable rate due 2038 0.14 % 35 35 3.625% and 4.00%, due 2028 and 2033 3.90 % 54 54 GENCO, variable rate due 2038 0.14 % 33 33 Other 3.65 % 1 1 Secured Senior Notes, 4.82%, due 2042 (8) 4.82 % 314 331 Term Loans, variable rates, due 2023 and 2024 (9) — 476 Tax-Exempt Financing, 1.7% due 2033 1.70 % 27 27 Virginia Electric and Power Company total principal (from above) 13,863 13,314 Dominion Energy, Inc. total principal (10) $ 37,694 $ 35,496 Fair value hedge valuation (11) 2 3 Securities due within one year (12) 2.79 % (805 ) (1,905 ) Supplemental 364-Day credit facility borrowings — (225 ) Unamortized discount, premium and debt issuance costs, net (315 ) (293 ) Derivative restructuring 738 773 Finance leases 112 108 Dominion Energy, Inc. total long-term debt $ 37,426 $ 33,957 (1) Represents weighted-average coupon rates for debt outstanding as of December 31, 2021. (2) These financings relate to certain pollution control equipment at Virginia Power’s generating facilities. (3) This $900 million supplemental credit facility, entered in June 2021, offers a reduced interest rate margin with respect to borrowed amounts allocated to certain environmental sustainability or social investment initiatives. Proceeds of the supplemental credit facility also may be used for general corporate purposes, but such proceeds are not eligible for a reduced interest rate margin. In June 2021 and August 2021, Dominion Energy borrowed $250 million and $650 million respectively. The proceeds from these borrowings were used to support environmental sustainability and social investment initiatives ($250 million) and for general corporate purposes ($650 million). In November 2021 and December 2021, Dominion Energy repaid $650 million and $250 million, respectively, borrowed under this arrangement. ( 4 ) Includes debt assumed by Dominion Energy from the merger of its former CNG subsidiary. (5) In August 2021, Dominion Energy redeemed the remaining principal outstanding of $800 million of its July 2016 hybrids, which would have otherwise matured in 2076. (6) The term loan amortizes over a 17-year period and matures in December 2024 with the potential to be extended to December 2026. The debt is secured by DECP Holdings’ noncontrolling interest in Cove Point. (7 ) Industrial revenue bonds totaling $68 million are secured by letters of credit that expire, subject to renewal, in the fourth quarter of 2022. ( 8 ) Represents debt associated with Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain solar facilities. (9) Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt was nonrecourse to Dominion Energy and was secured by SBL Holdco’s and Dominion Solar Projects III, Inc’s interest in certain solar facilities. In connection with the sales of certain non-wholly owned nonregulated solar facilities discussed in Note 10, the outstanding debt of SBL Holdco was assumed by Terra Nova Renewable Partners and Dominion Energy utilized proceeds from Clearway to repay the outstanding balance of the Dominion Solar Projects III, Inc. term loan. ( 10 ) Excludes amounts classified as held for sale at December 31, 2020. See Note 3. ( 11 ) Represents the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt. ( 12 ) At December 31, 2020, includes $22 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc.
Schedule Of Principal Payments Of Long Term Debt Table Text Block	Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2021, were as follows: 2022 2023 2024 2025 2026 Thereafter Total (millions, except percentages) Virginia Power Unsecured Senior Notes $ 300 $ 700 $ 350 $ 350 $ 1,150 $ 10,388 $ 13,238 Tax-Exempt Financings — — — — — 625 625 Total $ 300 $ 700 $ 350 $ 350 $ 1,150 $ 11,013 $ 13,863 Weighted-average Coupon 3.45 % 2.75 % 3.45 % 3.10 % 3.08 % 4.16 % Dominion Energy Term Loans $ 151 $ 134 $ 2,215 $ — $ — $ — $ 2,500 First Mortgage Bonds — — — — — 3,634 3,634 Unsecured Senior Notes 650 2,700 690 2,000 2,257 20,779 29,076 Secured Senior Notes 6 17 31 19 20 221 314 Tax-Exempt Financings — — — — — 775 775 Unsecured Junior Subordinated Notes Payable to Affiliated Trusts — — — — — 10 10 Unsecured Junior Subordinated Notes — — 700 — — — 700 Enhanced Junior Subordinated Notes — — — — — 685 685 Total $ 807 $ 2,851 $ 3,636 $ 2,019 $ 2,277 $ 26,104 $ 37,694 Weighted-average Coupon 2.79 % 1.89 % 2.20 % 3.01 % 2.82 % 4.26 %

Preferred Stock (Tables)

Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2021
Preferred Stock
Preferred Stock	Selected information about Dominion Energy’s 2019 Equity Units is presented below: Issuance Date Units Issued Total Net Proceeds (1) Total Preferred Stock (2) Cumulative Dividend Rate Stock Purchase Contract Annual Rate Stock Purchase Contract Liability (3) Stock Purchase Contract Settlement Date (millions except interest rates) 6/14/2019 16 $ 1,582 $ 1,610 1.75 % 5.5 % $ 250 6/1/2022 (1) Issuance costs of $28 million were recorded as a reduction to preferred stock ($14 million) and common stock ($14 million). (2) (3) Payments of $85 million, $83 million and $38 million were made in 2021, 2020 and 2019, respectively. The stock purchase contract liability was $44 million and $129 million at December 31, 2021 and 2020, respectively.

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2021
Schedule of Changes in AOCI Net of Tax and Reclassifications out of AOCI by Component	The following table presents Dominion Energy’s changes in AOCI (net of tax) and reclassifications out of AOCI by component: Commodity Interest Rate Foreign Currency Total Derivative-Hedging Activities (1) Investment Securities (2) Pension and other postretirement benefit costs (3) Equity Method Investees (4) Total (millions) Year Ended December 31, 2021 Beginning balance $ (1 ) $ (418 ) $ — $ (419 ) $ 62 $ (1,359 ) $ (1 ) $ (1,717 ) Other comprehensive income before reclassifications: gains (losses) — 15 — 15 (7 ) 144 (3 ) 149 Amounts reclassified from AOCI: (gains) losses Purchased gas 1 — — 1 — — — 1 Interest and related charges — 60 — 60 — — — 60 Other income — — — — (23 ) 111 — 88 Total 1 60 — 61 (23 ) 111 — 149 Income tax expense — (15 ) — (15 ) 5 (29 ) — (39 ) Total, net of tax 1 45 — 46 (18 ) 82 — 110 Net current period other comprehensive income (loss) 1 60 — 61 (25 ) 226 (3 ) 259 Ending balance $ — $ (358 ) $ — $ (358 ) $ 37 $ (1,133 ) $ (4 ) $ (1,458 ) Year Ended December 31, 2020 Beginning balance $ 16 $ (426 ) $ 3 $ (407 ) $ 37 $ (1,421 ) $ (2 ) $ (1,793 ) Other comprehensive income before reclassifications: gains (losses) — (231 ) (8 ) (239 ) 43 25 1 (170 ) Amounts reclassified from AOCI: (gains) losses Operating revenue (25 ) — — (25 ) — — — (25 ) Purchased gas 4 — — 4 — — — 4 Discontinued operations (2 ) 236 6 240 — — — 240 Interest and related charges — 83 — 83 — — — 83 Other income — — — — (24 ) 50 — 26 Total (23 ) 319 6 302 (24 ) 50 — 328 Income tax expense 6 (80 ) (1 ) (75 ) 6 (13 ) — (82 ) Total, net of tax (17 ) 239 5 227 (18 ) 37 — 246 Net current period other comprehensive income (loss) (17 ) 8 (3 ) (12 ) 25 62 1 76 Ending balance $ (1 ) $ (418 ) $ — $ (419 ) $ 62 $ (1,359 ) $ (1 ) $ (1,717 ) (1) Net of $119 million (2) Net of $(10) million and $(21) million tax at December 31, 2021 and 2020, respectively. (3) Net of $396 million and $478 million tax at December 31, 2021 and 2020, respectively. (4) Net of $1 million and $— million tax at December 31, 2021 and 2020, respectively.
Summary of Restricted Stock Activity	The following table provides a summary of restricted stock activity for the years ended December 31, 2021, 2020 and 2019: Shares Weighted - average Grant Date Fair Value (thousands) Nonvested at December 31, 2018 1,208 $ 73.03 Granted 614 76.49 Vested (324 ) 71.75 Cancelled and forfeited (96 ) 77.16 Nonvested at December 31, 2019 1,402 $ 74.77 Granted 531 81.74 Vested (424 ) 74.39 Cancelled and forfeited (99 ) 81.59 Nonvested at December 31, 2020 1,410 $ 77.41 Granted 518 71.78 Vested (505 ) 73.54 Cancelled and forfeited (113 ) 75.57 Nonvested at December 31, 2021 1,310 $ 76.65
Virginia Electric and Power Company
Schedule of Changes in AOCI Net of Tax and Reclassifications out of AOCI by Component	The following table presents Virginia Power’s changes in AOCI (net of tax) and reclassification out of AOCI by component: Interest Rate Total Derivative-Hedging Activities (1) Investment Securities (2) Total (millions) Year Ended December 31, 2021 Beginning balance $ (60 ) $ (60 ) $ 8 $ (52 ) Other comprehensive income before reclassifications: gains (losses) 13 13 (2 ) 11 Amounts reclassified from AOCI: (gains) losses Interest and related charges 3 3 — 3 Other income — — (3 ) (3 ) Total 3 3 (3 ) — Income tax expense (1 ) (1 ) 1 — Total, net of tax 2 2 (2 ) — Net current period other comprehensive income (loss) 15 15 (4 ) 11 Ending balance $ (45 ) $ (45 ) $ 4 $ (41 ) Year Ended December 31, 2020 Beginning balance $ (34 ) $ (34 ) $ 5 $ (29 ) Other comprehensive income before reclassifications: gains (losses) (28 ) (28 ) 6 (22 ) Amounts reclassified from AOCI: (gains) losses Interest and related charges 2 2 — 2 Other income — — (4 ) (4 ) Total 2 2 (4 ) (2 ) Income tax expense — — 1 1 Total, net of tax 2 2 (3 ) (1 ) Net current period other comprehensive income (loss) (26 ) (26 ) 3 (23 ) Ending balance $ (60 ) $ (60 ) $ 8 $ (52 ) (1) Net of $16 million and (2) Net of $(2) million and $(3) million tax at December 31, 2021 and 2020, respectively.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2021
Compensation And Retirement Disclosure [Abstract]
Pension Plan and Other Postretirement Benefit Plan Obligations and Plan Assets and Includes a Statement of the Plans Funded Status	The following table summarizes the changes in pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans’ funded status for Dominion Energy: Pension Benefits Other Postretirement Benefits Year Ended December 31, 2021 2020 2021 2020 (millions, except percentages) Dominion Energy Changes in benefit obligation: Benefit obligation at beginning of year $ 11,363 $ 10,446 $ 1,746 $ 1,769 Service cost 170 173 25 28 Interest cost 317 351 46 58 Benefits paid (488 ) (461 ) (105 ) (120 ) Actuarial (gains) losses during the year (413 ) 992 (161 ) 33 Plan amendments — — (14 ) (6 ) Settlements and curtailments (1) (59 ) (138 ) — (16 ) Benefit obligation at end of year $ 10,890 $ 11,363 $ 1,537 $ 1,746 Changes in fair value of plan assets: Fair value of plan assets at beginning of year $ 10,979 $ 9,631 $ 2,100 $ 1,880 Actual return (loss) on plan assets 1,202 1,602 294 300 Employer contributions 284 278 — 13 Benefits paid (488 ) (461 ) (71 ) (93 ) Settlements (2) (32 ) (71 ) — — Fair value of plan assets at end of year $ 11,945 $ 10,979 $ 2,323 $ 2,100 Funded status at end of year $ 1,055 $ (384 ) $ 786 $ 354 Amounts recognized in the Consolidated Balance Sheets at December 31: Noncurrent pension and other postretirement benefit assets $ 1,246 $ 1,054 $ 1,064 $ 650 Other current liabilities (12 ) (14 ) (15 ) (15 ) Noncurrent pension and other postretirement benefit liabilities (179 ) (1,424 ) (263 ) (281 ) Net amount recognized $ 1,055 $ (384 ) $ 786 $ 354 Significant assumptions used to determine benefit obligations as of December 31: Discount rate 3.06%-3.19% 2.73%–2.95% 3.04%-3.11% 2.69%–2.80% Weighted average rate of increase for compensation 4.51% 4.53% n/a n/a Crediting interest rate for cash balance and similar plans 1.81%-1.94% 1.93% - 2.15% n/a n/a (1) 2021 amounts include curtailments and settlements recognized primarily as a result of the employee choice program and settlements of nonqualified pension obligations. 2020 amounts include curtailment and settlements recognized as a result of the GT&S Transaction as well as settlements of qualified and nonqualified pension obligations. (2) 2021 amounts relate to settlements of nonqualified pension obligations and 2020 amounts relate primarily to settlements of qualified and nonqualified pension obligations.
Benefit Obligation in Excess of Plan Asset	The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets for Dominion Energy: Pension Benefits Other Postretirement Benefits As of December 31, 2021 2020 2021 2020 (millions) Dominion Energy Benefit obligation $ 9,420 $ 10,697 $ 261 $ 305 Fair value of plan assets 9,229 9,259 7 9
Accumulated Benefit Obligation in Excess of Plan Assets	The following table provides information on the ABO and fair value of plan assets for Dominion Energy’s pension plans with an ABO in excess of plan assets: As of December 31, 2021 2020 (millions) Accumulated benefit obligation $ 127 $ 9,970 Fair value of plan assets 53 9,259
Benefit Payments Expected Future Service	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for Dominion Energy’s plans: Estimated Future Benefit Payments Pension Benefits Other Postretirement Benefits (millions) Dominion Energy 2022 $ 513 $ 101 2023 516 100 2024 529 99 2025 541 97 2026 548 96 2027-2031 2,833 450
Fair Values of Pension and Post Retirement Plan Assets by Asset Category	The fair values of Dominion Energy’s pension plan assets by asset category are as follows: At December 31, 2021 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 25 $ 5 $ — $ 30 $ 20 $ 1 $ — $ 21 Common and preferred stocks: U.S. (1) 2,592 244 — 2,836 2,405 — — 2,405 International 1,773 19 — 1,792 1,727 — — 1,727 Insurance contracts — 279 — 279 — 409 — 409 Corporate debt instruments 81 1,439 — 1,520 32 1,385 — 1,417 Government securities 39 914 — 953 30 772 — 802 Total recorded at fair value $ 4,510 $ 2,900 $ — $ 7,410 $ 4,214 $ 2,567 $ — $ 6,781 Assets recorded at NAV (2) Common/collective trust funds 3,010 2,905 Alternative investments: Real estate funds 116 108 Private equity funds 1,233 856 Debt funds 162 168 Hedge funds 14 13 Total recorded at NAV $ 4,535 $ 4,050 Total investments (3) $ 11,945 $ 10,831 (1) Includes $258 million of Dominion Energy preferred stock and no Dominion Energy common stock at December 31, 2021 and $365 million of Dominion Energy common stock at December 31, 2020. (2) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient are not required to be categorized in the fair value hierarchy. (3) Excludes net assets related to pending sales of securities of $35 million, net accrued income of $27 The fair values of Dominion Energy’s other postretirement plan assets by asset category are as follows: At December 31, 2021 2020 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions) Dominion Energy Cash and cash equivalents $ 3 $ 1 $ — $ 4 $ — $ 2 $ — $ 2 Common and preferred stocks: U.S. 898 14 — 912 817 — — 817 International 256 1 — 257 240 — — 240 Insurance contracts — 16 — 16 — 23 — 23 Corporate debt instruments 5 61 — 66 2 60 — 62 Government securities 2 47 — 49 2 42 — 44 Total recorded at fair value $ 1,164 $ 140 $ — $ 1,304 $ 1,061 $ 127 $ — $ 1,188 Assets recorded at NAV (1) Common/collective trust funds 840 765 Alternative investments: Real estate funds 13 10 Private equity funds 152 117 Debt funds 9 10 Hedge funds 1 1 Total recorded at NAV $ 1,015 $ 903 Total investments (2) $ 2,319 $ 2,091 (1) These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient are not required to be categorized in the fair value hierarchy. (2) Excludes net assets related to pending sales of securities of $5 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2021. Excludes net assets related to pending sales of securities of $10 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2020.
Net Periodic Benefit (Credit) Cost and Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	The components of the provision for net periodic benefit (credit) cost and amounts recognized in other comprehensive income and regulatory assets and liabilities for Dominion Energy plans are as follows: Pension Benefits Other Postretirement Benefits Year Ended December 31, 2021 2020 2019 2021 2020 2019 (millions, except percentages) Dominion Energy Service cost $ 170 $ 173 $ 162 $ 25 $ 28 $ 26 Interest cost 317 351 394 46 58 68 Expected return on plan assets (834 ) (777 ) (708 ) (173 ) (156 ) (140 ) Amortization of prior service (credit) cost — 1 1 (42 ) (49 ) (52 ) Amortization of net actuarial loss 193 206 172 4 6 10 Settlements, curtailments and special termination benefits 10 14 72 — (59 ) 42 Net periodic benefit (credit) cost $ (144 ) $ (32 ) $ 93 $ (140 ) $ (172 ) $ (46 ) Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities: Current year net actuarial (gain) loss $ (782 ) $ 166 $ 16 $ (282 ) $ (110 ) $ (98 ) Prior service (credit) cost — — — (13 ) (6 ) 2 Settlements and curtailments (36 ) (81 ) 6 — 59 — Less amounts included in net periodic benefit cost: Amortization of net actuarial loss (193 ) (206 ) (172 ) (4 ) (6 ) (10 ) Amortization of prior service credit (cost) — (1 ) (1 ) 42 49 52 Total recognized in other comprehensive income and regulatory assets and liabilities $ (1,011 ) $ (122 ) $ (151 ) $ (257 ) $ (14 ) $ (54 ) Significant assumptions used to determine periodic cost: Discount rate 2.73%-3.29% 2.77%-3.63% 3.57%-4.43% 2.69%-2.80% 3.07%-3.52% 4.05% to 4.41% Expected long-term rate of return on plan assets 7.00%-8.45% 7.00%-8.60% 7.00% -8.65% 8.45% 8.50% 8.50% Weighted average rate of increase for compensation 4.53% 4.23% 4.20% n/a n/a n/a Crediting interest rate for cash balance and similar plans 1.93%-2.15% 2.31-2.83% 2.77-3.63% n/a n/a n/a Healthcare cost trend rate (1) 6.25% 6.25% 6.50% to 6.60% Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (1) 5.00% 5.00% 5.00% Year that the rate reaches the ultimate trend rate (1) 2026-2027 2025-2026 2023-2025 (1) Assumptions used to determine net periodic cost for the following year.
Components of AOCI and Regulatory Assets and Liabilities that have Not been Recognized as Components of Periodic Benefit (Credit) Cost	The components of AOCI and regulatory assets and liabilities for Dominion Energy’s plans that have not been recognized as components of net periodic benefit (credit) cost are as follows: Pension Benefits Other Postretirement Benefits At December 31, 2021 2020 2021 2020 (millions) Dominion Energy Net actuarial loss $ 2,198 $ 3,207 $ (166 ) $ 120 Prior service (credit) cost 2 4 (203 ) (232 ) Total (1) $ 2,200 $ 3,211 $ (369 ) $ (112 ) (1) As of December 31, 2021, of the $2.2 billion and $(369) million related to pension benefits and other postretirement benefits, $1.7 billion and $(155) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2020, of the $ billion and $ ( 112 ) million related to pension benefits and other postretirement benefits, $ 1.9 billion and $( 40 ) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2021
Commitments And Contingencies Disclosure [Abstract]
Nuclear Insurance	The current levels of nuclear property insurance coverage for the Companies’ nuclear units are as follows: Coverage (billions) Dominion Energy Millstone $ 1.06 Kewaunee 0.05 Summer 2.75 Virginia Power Surry $ 1.06 North Anna 1.06
Long-term Purchase Commitment	At December 31, 2021, Dominion Energy had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that a third party has used to secure financing for the facility that will provide the contracted goods or services: 2022 2023 2024 2025 2026 Thereafter Total (millions) Purchased electric capacity (1) $ 66 $ 66 $ 66 $ 65 $ 68 $ 681 $ 1,012 (1) Commitments represent estimated amounts payable for energy under power purchase contracts with qualifying facilities which expire at various dates through 2046. Energy payments are generally based on fixed dollar amounts per month and totaled $59 million and $52 million for the years ended December 31, 2021 and 2020, respectively.
Schedule of Subsidiary Guarantees	At December 31, 2021, Dominion Energy had issued the following subsidiary guarantees : Maximum Exposure (millions) Commodity transactions (1) $ 2,077 Nuclear obligations (2) 243 Solar (3) 321 Other (4) 1,282 Total (5) $ 3,923 (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 primarily related to certain DGI subsidiaries regarding all aspects of running a nuclear facility. (3) 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. (4) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Also includes guarantees entered into by Dominion Energy RNG Holdings, II, Inc. on behalf of a subsidiary to facilitate construction of renewable natural gas facilities. Due to the uncertainty of workers’ compensation claims, the parental guarantee has no stated limit. (5) Excludes Dominion Energy’s guarantees for the new corporate office property and an offshore wind installation vessel discussed in Note 15.

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2021
Virginia Electric and Power Company
Schedule of Related Party Transactions	Presented below are Virginia Power’s significant transactions with DES and other affiliates: Year Ended December 31, 2021 2020 2019 (millions) Commodity purchases from affiliates $ 742 $ 569 $ 690 Services provided by affiliates (1) 494 455 503 Services provided to affiliates 18 18 24 (1) Includes capitalized expenditures of $161 million, $141 million and $133 million for the year ended December 31, 2021, 2020 and 2019, respectively.

Operating Segments (Tables)

Operating Segments (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting Information [Line Items]
Schedule of Primary 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 Virginia Regulated electric distribution X X Regulated electric transmission X X Regulated electric generation fleet (1) X X Gas Distribution Regulated gas distribution and storage (2) X Dominion Energy South Carolina Regulated electric distribution X Regulated electric transmission X Regulated electric generation fleet X Regulated gas distribution and storage X Contracted Assets Nonregulated electric generation fleet (3) X Noncontrolling interest in Cove Point X (1) I ncludes Virginia Power’s non-jurisdictional generation operations. (2) (3) Includes solar generation facility development operations.
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Dominion Energy’s operations: Year Ended December 31, Dominion Energy Virginia Gas Distribution Dominion Energy South Carolina Contracted Assets Corporate and Other Adjustments & Eliminations Consolidated Total (millions) 2021 Total revenue from external customers $ 8,012 $ 2,660 $ 2,968 $ 1,018 $ (759 ) $ 60 $ 13,959 Intersegment revenue (13 ) 5 7 67 943 (1,004 ) 5 Total operating revenue 7,999 2,665 2,975 1,085 184 (944 ) 13,964 Depreciation, depletion and amortization 1,299 380 486 162 151 — 2,478 Equity in earnings of equity method investees — — (3 ) 259 20 — 276 Interest income 13 6 10 81 17 (26 ) 101 Interest and related charges 537 86 206 52 499 (26 ) 1,354 Income tax expense (benefit) 462 116 125 112 (390 ) — 425 Net income from discontinued operations — — — — 641 — 641 Net income (loss) attributable to Dominion Energy 1,919 600 437 431 (99 ) — 3,288 Investment in equity method investees (1) — 106 — 2,738 88 — 2,932 Capital expenditures 3,762 1,252 694 277 76 — 6,061 Total assets (billions) 50.3 18.5 16.4 12.3 7.1 (5.0 ) 99.6 2020 Total revenue from external customers $ 7,802 $ 2,345 $ 2,782 $ 1,020 $ 200 $ 48 $ 14,197 Intersegment revenue (15 ) 10 5 51 963 (1,039 ) (25 ) Total operating revenue 7,787 2,355 2,787 1,071 1,163 (991 ) 14,172 Depreciation, depletion and amortization 1,247 344 474 182 85 — 2,332 Equity in earnings of equity method investees — — (1 ) 35 6 — 40 Interest income 13 6 12 91 73 (88 ) 107 Interest and related charges 527 76 219 75 568 (88 ) 1,377 Income tax expense (benefit) 496 121 107 (16 ) (625 ) — 83 Net income (loss) from discontinued operations — — — 167 (2,045 ) — (1,878 ) Net income (loss) attributable to Dominion Energy 1,891 560 419 402 (3,673 ) — (401 ) Investment in equity method investees (1) — 55 — 2,784 95 — 2,934 Capital expenditures 3,406 1,151 700 649 425 — 6,331 Total assets (billions) 46.0 17.1 16.0 13.1 8.6 (4.9 ) 95.9 2019 Total revenue from external customers $ 8,170 $ 2,367 $ 2,948 $ 1,083 $ (239 ) $ 79 $ 14,408 Intersegment revenue (13 ) 18 4 73 1,071 (1,160 ) (7 ) Total operating revenue 8,157 2,385 2,952 1,156 832 (1,081 ) 14,401 Depreciation, depletion and amortization 1,216 335 452 180 100 — 2,283 Equity in earnings of equity method investees — 2 (4 ) (1 ) 11 — 8 Interest income 11 4 9 97 112 (136 ) 97 Interest and related charges 530 116 242 98 636 (136 ) 1,486 Income tax expense (benefit) 482 114 163 20 (570 ) — 209 Net income from discontinued operations — — — 183 533 — 716 Net income (loss) attributable to Dominion Energy 1,786 487 430 460 (1,805 ) — 1,358 Capital expenditures 3,002 853 562 367 537 — 5,321 (1) Excludes liability to Atlantic Coast Pipeline.
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment	The following table presents segment information pertaining to Virginia Power’s operations: Year Ended December 31, Dominion Energy Virginia Corporate and Other Consolidated Total (millions) 2021 Operating revenue $ 7,976 $ (506 ) $ 7,470 Depreciation and amortization 1,296 68 1,364 Interest income 11 — 11 Interest expense (benefit) and related charges 535 (1 ) 534 Income tax expense (benefit) 467 (70 ) 397 Net income (loss) 1,914 (202 ) 1,712 Capital expenditures 3,756 — 3,756 Total assets (billions) 47.9 — 47.9 2020 Operating revenue $ 7,763 $ — $ 7,763 Depreciation and amortization 1,245 7 1,252 Interest income 11 — 11 Interest expense (benefit) and related charges 524 (8 ) 516 Income tax expense (benefit) 500 (271 ) 229 Net income (loss) 1,884 (863 ) 1,021 Capital expenditures 3,372 — 3,372 Total assets (billions) 43.7 — 43.7 2019 Operating revenue $ 8,137 $ (29 ) $ 8,108 Depreciation and amortization 1,215 8 1,223 Interest income 11 — 11 Interest expense (benefit) and related charges 529 (5 ) 524 Income tax expense (benefit) 481 (217 ) 264 Net income (loss) 1,783 (634 ) 1,149 Capital expenditures 2,981 — 2,981

Nature of Operations (Details)

Nature of Operations (Details)	12 Months Ended
	Dec. 31, 2021Segment
Segment Reporting Information [Line Items]
Number of operating segments	4
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Number of operating segments	1

Significant Accounting Polici_4

Significant Accounting Policies (Narrative) (Detail)

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 31, 2022USD ($)$ / shares

Mar. 31, 2020USD ($)

Sep. 30, 2019USD ($)

May 31, 2019USD ($)

Mar. 31, 2019USD ($)FacilityMW

Jan. 31, 2019USD ($)

Mar. 31, 2021USD ($)

Dec. 31, 2021USD ($)MWh$ / shares

Dec. 31, 2020USD ($)MWh

Dec. 31, 2019USD ($)

Jan. 01, 2019USD ($)

Significant Accounting Policies [Line Items]

Accrued unbilled revenue

$ 779,000,000

$ 1,100,000,000

Reversal of interest expense on uncertain tax positions effectively settled

21,000,000

Reversal of penalty expense on uncertain tax positions effectively settled

7,000,000

Margin deposit assets

678,000,000

19,000,000

Margin liabilities

0

5,000,000

Capitalized interest costs and Capitalized interest costs and AFUDC

117,000,000

103,000,000

$ 78,000,000

Impairment of assets and other charges

$ 195,000,000

$ 2,105,000,000

1,520,000,000

Finite Lived Intangible Asset Useful Life

35 years

Estimated proved developed or proved gas and oil reserves rate per unit | MWh

1.92

1.97

Operating lease assets

$ 506,000,000

[1]

$ 564,000,000

[1]

$ 504,000,000

Operating lease liability

$ 508,000,000

Accounting Standards Update 2016-02

Significant Accounting Policies [Line Items]

Change in Accounting Principle, Accounting Standards Update, Adopted [true false]

true

Change in Accounting Principle, Accounting Standards Update, Adoption Date

Jan. 1, 2019

Discontinued Operations | GT&S and Q-Pipe Transactions

Significant Accounting Policies [Line Items]

Operating lease assets

$ 43,000,000

Operating lease liability

$ 43,000,000

Non-jurisdictional and Certain Nonutility Solar Generation Facilities | Subsequent Event

Significant Accounting Policies [Line Items]

Finite Lived Intangible Asset Useful Life

35 years

Change in Depreciation Rates from New Depreciation Study

Significant Accounting Policies [Line Items]

Increase in EPS | $ / shares

$ 0.03

Revision Of Estimated Useful Life | Non-jurisdictional and Certain Nonutility Solar Generation Facilities | Subsequent Event

Significant Accounting Policies [Line Items]

Increase (decrease) in depreciation expense

$ (20,000,000)

Increase (decrease) in depreciation expense, after tax

$ (15,000,000)

Increase in EPS | $ / shares

$ 0.02

Impairment of Assets and Other Charges

Significant Accounting Policies [Line Items]

Impairment of assets and other charges

$ 26,000,000

Asset impairment charges after tax

19,000,000

Minimum

Significant Accounting Policies [Line Items]

Lessee Operating Lease Renewal Term

1 year

Maximum

Significant Accounting Policies [Line Items]

Lessee Operating Lease Renewal Term

70 years

Virginia Electric and Power Company

Significant Accounting Policies [Line Items]

Accrued unbilled revenue

$ 398,000,000

740,000,000

Percentage of fuel currently subject to deferred fuel accounting

86.00%

Margin deposit assets

$ 167,000,000

1,000,000

Margin liabilities

0

0

Capitalized interest costs and Capitalized interest costs and AFUDC

78,000,000

60,000,000

34,000,000

AFUDC recorded as regulatory asset

35,000,000

11,000,000

$ 11,000,000

MW Capacity | MW

1,292

Number of facilities in cold reserve units retired | Facility

6

Operating lease assets

256,000,000

[1]

185,000,000

[1]

$ 209,000,000

Operating lease liability

252,000,000

Virginia Electric and Power Company | Subsequent Event

Significant Accounting Policies [Line Items]

Finite Lived Intangible Asset Useful Life

35 years

Virginia Electric and Power Company | Change in Depreciation Rates from New Depreciation Study

Significant Accounting Policies [Line Items]

Increase (decrease) in depreciation expense

(31,000,000)

Increase (decrease) in depreciation expense, after tax

(23,000,000)

Virginia Electric and Power Company | Revision Of Estimated Useful Life | Subsequent Event

Significant Accounting Policies [Line Items]

Increase (decrease) in depreciation expense

$ (8,000,000)

Increase (decrease) in depreciation expense, after tax

$ (6,000,000)

Virginia Electric and Power Company | Electric Generation Facilities

Significant Accounting Policies [Line Items]

Charges recorded with dismantling

54,000,000

Charges recorded with dismantling after tax

40,000,000

Virginia Electric and Power Company | Impairment of Assets and Other Charges

Significant Accounting Policies [Line Items]

Impairment of assets and other charges

$ 751,000,000

17,000,000

$ 62,000,000

$ 346,000,000

$ 160,000,000

$ 76,000,000

127,000,000

Asset impairment charges after tax

$ 559,000,000

$ 12,000,000

$ 46,000,000

$ 257,000,000

$ 119,000,000

$ 56,000,000

94,000,000

Virginia Electric and Power Company | Affiliated Entity

Significant Accounting Policies [Line Items]

Income tax receivable

35,000,000

Income tax payable

19,000,000

Virginia Electric and Power Company | Affiliated Entity | Federal

Significant Accounting Policies [Line Items]

Income tax receivable

33,000,000

Income tax payable

17,000,000

Virginia Electric and Power Company | Affiliated Entity | State

Significant Accounting Policies [Line Items]

Income tax receivable

$ 2,000,000

Income tax payable

2,000,000

DESC

Significant Accounting Policies [Line Items]

Percentage of fuel currently subject to deferred fuel accounting

96.00%

Dominion Energy Gas Holdings, LLC

Significant Accounting Policies [Line Items]

Inventory under LIFO method

$ 26,000,000

2,000,000

Amount exceeded on LIFO basis

$ 74,000,000

$ 52,000,000

Cove Point | Brookfield

Significant Accounting Policies [Line Items]

Percentage of equity interest sold to noncontrolling interest owners

25.00%

Four Brothers And Three Cedars | Dominion Energy Midstream Partners, LP | Terra Nova Renewable Partners | Nonregulated Solar Projects

Significant Accounting Policies [Line Items]

Percentage of equity interest sold to noncontrolling interest owners

33.00%

[1]

Included in other deferred charges and other assets in the Companies’ Consolidated Balance Sheets.

Significant Accounting Polici_5

Significant Accounting Policies (Checks the Outstanding Accounts Payable but not yet Presented for Payment and Recorded) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accounts Payable [Line Items]
Accounts payable for checks outstanding	$ 70	$ 50
Virginia Electric and Power Company
Accounts Payable [Line Items]
Accounts payable for checks outstanding	$ 15	$ 30

Significant Accounting Polici_6

Significant Accounting Policies (Reconciliation of Total Cash, Restricted Cash and Equivalents) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	[1]	$ 283	$ 179	$ 166	$ 268
Cash and cash equivalents		283	172
Restricted cash and equivalents	[2],[3]	125	68	103	123
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		408	247	269	391
Virginia Electric and Power Company
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents		26	35	17	29
Restricted cash and equivalents	[3]			7	9
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows		$ 26	$ 35	$ 24	$ 38
[1]	At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $7 million, $31 million and $110 million of cash and cash equivalents included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021.
[2]	At December 31, 2020, December 31, 2019 and December 31, 2018, Dominion Energy had $3 million, $12 million and $89 million of restricted cash included in current assets held for sale, respectively. No amounts were included in current assets held for sale at December 31, 2021.
[3]	Restricted cash and equivalent balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.

Significant Accounting Polici_7

Significant Accounting Policies (Reconciliation of Total Cash, Restricted Cash and Equivalents) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	$ 283	$ 172
Current Assets Held for Sale
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	0	7	$ 31	$ 110
Restricted cash	$ 0	$ 3	$ 12	$ 89

Significant Accounting Polici_8

Significant Accounting Policies (Schedule of Supplemental Cash Flow Information) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule Of Supplemental Cash Flow Information [Line Items]
Interest and related charges, excluding capitalized amounts		$ 1,340	$ 1,519	$ 1,643
Income taxes		160	292	106
Significant noncash investing and financing activities:
Accrued capital expenditures	[1],[2],[3],[4],[5]	637	485	555
Leases	[1],[2],[3],[4],[5],[6]	96	173	157
Virginia Electric and Power Company
Schedule Of Supplemental Cash Flow Information [Line Items]
Interest and related charges, excluding capitalized amounts		501	491	495
Income taxes		109	452	272
Significant noncash investing and financing activities:
Accrued capital expenditures	[5],[7]	363	262	292
Leases	[5],[7],[8]	$ 79	$ 32	$ 55
[1]	See Note 3 for noncash investing and financing activities related to the SCANA Combination.
[2]	See Note 5 for noncash activities related to the sale of a noncontrolling interest in Cove Point.
[3]	See Note 9 for noncash investing activities related to the acquisition of a noncontrolling interest in Wrangler.
[4]	See Notes 18,19 and 20 for noncash financing activities related to the acquisition of the public interest in Dominion Energy Midstream, the remarketing of RSNs, the issuance of stock purchase contracts associated with the 2019 Equity Units, the contribution of stock to Dominion Energy’s qualified defined benefit pension plan, derivative restructuring and the issuance of common stock associated with the settlement of litigation. See Note 23 for non-cash investing activities related to property, plant and equipment conveyed to satisfy litigation.
[5]	See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.
[6]	Includes $47 million of finance leases and $49 million of operating leases entered in 2021, $46 million of finance leases and $127 million of operating leases entered in 2020 and $113 million of finance leases and $44 million of operating leases entered in 2019.
[7]	See Note 18 for non-cash financing activities related to derivative restructuring.
[8]	Includes $37 million of finance leases and $42 million of operating leases entered in 2021, $32 million of finance leases entered in, 2020 and $20 million of finance leases and $35 million of operating leases entered in 2019.

Significant Accounting Polici_9

Significant Accounting Policies (Schedule of Supplemental Cash Flow Information) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule Of Supplemental Cash Flow Information [Line Items]
Financing leases	$ 47	$ 46	$ 113
Operating leases	49	127	44
Virginia Electric and Power Company
Schedule Of Supplemental Cash Flow Information [Line Items]
Financing leases	37	$ 32	20
Operating leases	$ 42		$ 35

Significant Accounting Polic_10

Significant Accounting Policies (Depreciation Rates and Estimated Useful Life) (Detail)		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Nonregulated Generation-Nuclear
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives		44 years
Nonregulated Generation Solar | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives		15 years
Nonregulated Generation Solar | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives		35 years
General and Other | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives		5 years
General and Other | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives		59 years
Generation
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	[1]	2.63%	2.51%	2.84%
Generation | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)		2.69%	2.52%	2.94%
Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	[1]	2.47%	2.48%	2.50%
Transmission | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)		2.51%	2.52%	2.54%
Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	[1]	2.76%	2.76%	2.80%
Distribution | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)		3.18%	3.19%	3.14%
Storage
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	[1]	1.79%	1.59%	1.49%
General and Other
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)	[1]	3.85%	4.35%	3.99%
General and Other | Virginia Electric and Power Company
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates on utility property, plant and equipment (percentage)		5.08%	5.09%	4.40%
[1]	Excludes rates for depreciation reported as discontinued operations.

Acquisitions and Dispositions_2

Acquisitions and Dispositions (Disposition of Gas Transmission & Storage Operations) (Narrative) (Detail) - USD ($)	Nov. 30, 2020	Dec. 31, 2021	Jul. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Oct. 31, 2021	Oct. 31, 2020	Jul. 31, 2020
Business Acquisition And Dispositions [Line Items]
Income tax expense	$ 336,000,000	$ 173,000,000		$ 425,000,000	$ 83,000,000	$ 209,000,000
Term Loan Credit Agreement
Business Acquisition And Dispositions [Line Items]
Credit facility, amount borrowed			$ 1,300,000,000
Credit facility, description				The agreement matured in December 2021 and bore interest at a variable rate.
Debt, maturity month and year			2021-12
GT&S Transaction
Business Acquisition And Dispositions [Line Items]
Operating revenue				$ 5,000,000	4,000,000	$ 6,000,000
Derivative payment								$ 165,000,000
GT&S Transaction | BHE
Business Acquisition And Dispositions [Line Items]
Disposal group, total value of consideration									$ 10,000,000,000
Disposal group, cash consideration					222,000,000				$ 4,000,000,000
Cash proceeds received	2,700,000,000
Disposal group, recognized a pre-tax gain upon closing	127,000,000
Goodwill write-off	$ 1,400,000,000
GT&S Transaction | BHE | Transition Service Agreement
Business Acquisition And Dispositions [Line Items]
Operating revenue				$ 21,000,000	$ 4,000,000
Disposal group, administrative services description				Dominion Energy will continue to provide specified administrative services to support the operations of the disposed business for up to 24 months after closing, subsequently extended through June 2023 for certain services.
GT&S Transaction | BHE | Cove Point
Business Acquisition And Dispositions [Line Items]
Percentage ownership in total units	50.00%
Disposal group, initial fair value	$ 2,800,000,000
GT&S Transaction | BHE | General Partner Interest
Business Acquisition And Dispositions [Line Items]
Percentage ownership in total units									100.00%
GT&S Transaction | BHE | Limited Partner Interests
Business Acquisition And Dispositions [Line Items]
Percentage ownership in total units									25.00%
Q-Pipe Group | BHE
Business Acquisition And Dispositions [Line Items]
Disposal group, cash consideration								$ 1,300,000,000
Q-Pipe Group | Southwest Gas
Business Acquisition And Dispositions [Line Items]
Disposal group, total value of consideration							$ 2,000,000,000
Disposal group, cash consideration							$ 1,500,000,000
Cash proceeds received		1,500,000,000
Disposal group, recognized a pre-tax gain upon closing		666,000,000		$ 666,000,000
Goodwill write-off		$ 191,000,000
Disposal group, administrative services description				Dominion Energy will continue to provide specified administrative services to support the operations of the disposed businesses for up to 12 months after closing, subject to extension.
Q-Pipe Transaction | BHE
Business Acquisition And Dispositions [Line Items]
Disposal group, including discontinued operation, deposits	$ 1,300,000,000

Acquisitions and Dispositions_3

Acquisitions and Dispositions (Schedule of Results of Operations of Disposal Groups Reported As Discontinued Operations) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income tax expense (benefit)		$ 188		$ (204)		$ 142
Net income (loss) including noncontrolling interests	[1],[2]	641		(1,878)		716
Net income (loss) attributable to Dominion Energy		641		(1,984)		705
GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Operating revenue		5		4		6
Income tax expense (benefit)		(17)
Disposition of GTS Operations | Q-Pipe Group
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Operating revenue		254	[3]	246		251
Operating expense	[4]	76	[3]	96		131
Other income (loss)	[5]	28	[3]	1		4
Interest and related charges	[6]	25	[3]	20		20
Income before income taxes		181	[3]	131		104
Income tax expense (benefit)	[7]	36	[3]	(9)		23
Net income (loss) including noncontrolling interests		145	[3]	140		81
Net income (loss) attributable to Dominion Energy		$ 145	[3]	140		81
Disposition of GTS Operations | GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Operating revenue				1,710	[3]	2,213
Operating expense	[4]			1,289	[3]	1,367
Other income (loss)	[5]			88	[3]	58
Interest and related charges	[6]			372	[3]	267
Income before income taxes				137	[3]	637
Income tax expense (benefit)	[7]			334	[3]	120
Net income (loss) including noncontrolling interests				(197)	[3]	517
Noncontrolling interests				106	[3]	11
Net income (loss) attributable to Dominion Energy				$ (303)	[3]	$ 506
[1]	Includes income tax expense (benefit) of $188 million, $(204) million and $142 million for the years ended December 31, 2021, 2020 and 2019, respectively
[2]	See Note 9 for amounts attributable to related parties
[3]	Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date.
[4]	GT&S Transaction includes a charge of $482 million ($359 million after-tax) recorded in the second quarter of 2020 associated with the probable abandonment of a significant portion of the Supply Header Project as well as the establishment of a $75 million ARO as a result of the cancellation of the Atlantic Coast Pipeline Project.
[5]	Q-Pipe Group includes a $25 million benefit associated with the termination of the Q-Pipe Transaction in the third quarter of 2021.
[6]	GT&S Transaction includes a loss of $237 million ($178 million after-tax) recorded in the third quarter of 2020 associated with cash flow hedges of debt-related items that were determined to be probable of not occurring.
[7]	Excludes $17 million income tax benefit recorded in 2021 associated with the GT&S Transaction.

Acquisitions and Dispositions_4

Acquisitions and Dispositions (Schedule of Results of Operations of Disposal Groups Reported As Discontinued Operations) (Parenthetical) (Detail) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Jun. 30, 2020	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Impairment of assets and other charges				$ 195		$ 2,105		$ 1,520
Asset retirement obligations				5,473	[1]	5,583	[1]	5,184
Income tax expense (benefit) from discontinued operations				188		$ (204)		$ 142
GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Loss associated with cash flow hedges of debt-related items		$ 237
Loss associated with cash flow hedges of debt-related items after tax		$ 178
Income tax expense (benefit) from discontinued operations				$ (17)
Q-Pipe Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Benefit associated with the termination	$ 25
Supply Header Project | GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Impairment of assets and other charges			$ 482
Asset impairment charges after tax			359
Atlantic Coast Pipeline Project | GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset retirement obligations			$ 75
[1]	Includes $179 million and $198 million reported in other current liabilities at December 31, 2020 and 2021, respectively

Acquisitions and Dispositions_5

Acquisitions and Dispositions (Schedule of Major Classes of Assets and Liabilities Reported As Held for Sale in Discontinued Operations) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	[1]	$ 25	$ 1,482
Current liabilities			625
Dominion Energy Gas Holdings, LLC | Q-Pipe Group
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	[2]		47
Equity method investments	[3]		35
Property, plant and equipment, net			1,113
Other deferred charges and other assets, including goodwill and intangible assets	[4]		224
Current liabilities			30
Long-term debt			426
Other deferred credits and liabilities			$ 154
[1]	See Note 9 for amounts attributable to related parties .
[2]	Includes cash and cash equivalents of $7 million.
[3]	Comprised of equity method investment in White River Hub.
[4]	Includes goodwill of $191 million.

Acquisitions and Dispositions_6

Acquisitions and Dispositions (Schedule of Major Classes of Assets and Liabilities Reported As Held for Sale in Discontinued Operations) (Parenthetical) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Goodwill	[1]	$ 7,405	$ 7,381	$ 7,395
Dominion Energy Gas Holdings, LLC | Q-Pipe Group
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Cash and cash equivalents			7
Goodwill			$ 191
[1]	Goodwill amounts do not contain any accumulated impairment losses.

Acquisitions and Dispositions_7

Acquisitions and Dispositions (Schedule of Capital Expenditures and Significant Noncash Items Reported As Discontinued Operations) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Significant noncash items
Charges related to a voluntary retirement program						$ 320
Depreciation, depletion and amortization		$ 2,478		$ 2,332		2,283
Accrued capital expenditures	[1],[2],[3],[4],[5]	637		485		555
Dominion Energy Gas Holdings, LLC | Q-Pipe Group
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Capital expenditures		$ 34	[6]	38		42
Significant noncash items
Impairment of assets and other charges						1
Charges related to a voluntary retirement program						3
Depreciation, depletion and amortization				27		51
Accrued capital expenditures				1		2
Dominion Energy Gas Holdings, LLC | GT&S Transaction
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Capital expenditures				292	[6]	386
Significant noncash items
Impairment of assets and other charges				469	[6]	13
Charges related to a voluntary retirement program						19
Depreciation, depletion and amortization				$ 177	[6]	322
Accrued capital expenditures						$ 25
[1]	See Note 3 for noncash investing and financing activities related to the SCANA Combination.
[2]	See Note 5 for noncash activities related to the sale of a noncontrolling interest in Cove Point.
[3]	See Note 9 for noncash investing activities related to the acquisition of a noncontrolling interest in Wrangler.
[4]	See Notes 18,19 and 20 for noncash financing activities related to the acquisition of the public interest in Dominion Energy Midstream, the remarketing of RSNs, the issuance of stock purchase contracts associated with the 2019 Equity Units, the contribution of stock to Dominion Energy’s qualified defined benefit pension plan, derivative restructuring and the issuance of common stock associated with the settlement of litigation. See Note 23 for non-cash investing activities related to property, plant and equipment conveyed to satisfy litigation.
[5]	See the New Accounting Standards section below for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.
[6]	Operations associated with the Q-Pipe Group are through the December 31, 2021 closing date. Operations associated with the GT&S Transaction are through the November 1, 2020 closing date.

Acquisitions and Dispositions_8

Acquisitions and Dispositions (Acquisition of SCANA) (Narrative) (Detail) - USD ($) shares in Millions, $ in Millions		1 Months Ended	2 Months Ended	3 Months Ended	12 Months Ended
		Jan. 31, 2019	Oct. 31, 2017	Mar. 31, 2019	Dec. 31, 2021	Dec. 31, 2019	Dec. 31, 2020
Business Acquisition And Dispositions [Line Items]
Stock issued during period for acquisition, value						$ 6,818
Regulatory Liabilities					$ 11,699		$ 10,996
Regulatory liabilities-current					986		$ 809
SCANA
Business Acquisition And Dispositions [Line Items]
Stock issued during period for acquisition, shares		95.6				95.6
Stock issued during period for acquisition, value		$ 6,800				$ 6,800
Common stock agreed to be issued, percentage		0.669%
Total outstanding debt		$ 6,900				6,707
Business combination, refund to customers		$ 2,000
Period to provide refund to customer		20 years	20 years
Regulatory Liabilities			$ 1,100
Regulatory liabilities-current			67
Refund Liability to electric service customers			1,000
Remaining regulatory asset	[1]					3,940
Other Commitment, Fiscal Year Maturity [Abstract]
Charitable contributions, annual committed increase for next five years					$ 1
SCANA | Minimum
Other Commitment, Fiscal Year Maturity [Abstract]
Charitable contributions, period committed for annual increase		5 years
SCANA | NND Project
Business Acquisition And Dispositions [Line Items]
Period to provide refund to customer		20 years
Business combination cost related to exclusion from rate recovery		$ 2,400
Remaining regulatory asset		2,800
Remaining regulatory asset current		138
SCANA | Dominion Energy South Carolina Inc
Business Acquisition And Dispositions [Line Items]
Period to provide refund to customer				11 years
Charge for refund of amounts from customers				$ 1,000
Charge for refund of amounts from customers, current				$ 137
After tax charge in statements of income						$ 756
SCANA | Toshiba Corporation
Business Acquisition And Dispositions [Line Items]
Cash proceeds received			$ 1,100
SCANA | Columbia Energy
Business Acquisition And Dispositions [Line Items]
Business combination cost related to exclusion from rate recovery		$ 180
[1]	Includes $258 million of certain income tax-related regulatory assets associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. See Note 5 for additional information.

Acquisitions and Dispositions_9

Acquisitions and Dispositions (Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 31, 2019
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Goodwill	[1]	$ 7,405	$ 7,381	$ 7,395
SCANA
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Total current assets	[2]			1,782
Investments	[3]			224
Property, plant and equipment	[4],[5]			11,006
Goodwill				2,609
Regulatory assets	[6]			3,940
Other deferred charges and other assets, including intangible assets	[7]			430
Total Assets				19,991
Total current liabilities	[8]			1,556
Total outstanding debt				6,707	$ 6,900
Deferred income taxes				1,068
Regulatory liabilities				2,706
Other deferred credits and other liabilities	[9]			1,115
Total Liabilities				13,152
Total purchase price	[10]			$ 6,839
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Includes $389 million of cash, restricted cash and equivalents, of which $115 million is considered restricted.
[3]	Includes $31 million for equity method investments. The fair value adjustment on the equity method investments is considered to be equity method goodwill and is not amortized.
[4]	Includes $105 million of certain property, plant and equipment associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. As a result, Dominion Energy’s Consolidated Statements of Income for the year ended December 31, 2019 include a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges (reflected in the Corporate and Other segment).
[5]	Nonregulated property, plant and equipment, excluding land, will be depreciated on a straight-line basis over the remaining useful lives of such property, primarily ranging from 5 to 78 years.
[6]	Includes $258 million of certain income tax-related regulatory assets associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. See Note 5 for additional information.
[7]	Intangible assets have an estimated weighted-average amortization period of approximately five years.
[8]	Includes $40 million outstanding under letters of credit advances, which were repaid in January 2019, as well as $173 million outstanding commercial paper under various credit facilities. All such credit facilities were terminated in 2019.
[9]	Includes a $379 million pension and other postretirement benefit liability.
[10]	Includes stock-based compensation awards with a fair value of $21 million.

Acquisitions and Disposition_10

Acquisitions and Dispositions (Schedule of Preliminary Allocation of Purchase Price to Assets Acquired and Liabilities Assumed) (Parenthetical) (Detail) - USD ($) $ in Millions		1 Months Ended	12 Months Ended
		Jan. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Cash, restricted cash and equivalents			$ 408	$ 247	$ 269	$ 391
Impairment of assets and other charges			$ 195	2,105	1,520
Intangible assets, estimated weighted-average amortization period			7 years
Repayment of letter of credit advances			$ 225
Pension and other postretirement benefit liability			442	1,706
SCANA
Business Acquisition [Line Items]
Cash, restricted cash and equivalents					389
Restricted cash					115
Equity method investment					31
Property, plant and equipment	[1],[2]				11,006
Impairment of assets and other charges			100	90	641
Impairment of assets and other charges, after tax			$ 75	$ 68	$ 480
Intangible assets, estimated weighted-average amortization period					5 years
Repayment of letter of credit advances		$ 40
Repayments of Commercial Paper		$ 173
Pension and other postretirement benefit liability					$ 379
Stock based compensation awards estimated fair value					$ 21
SCANA | Minimum
Business Acquisition [Line Items]
Property, plant and equipment, estimated useful lives					5 years
SCANA | Maximum
Business Acquisition [Line Items]
Property, plant and equipment, estimated useful lives					78 years
SCANA | NND Project
Business Acquisition [Line Items]
Property, plant and equipment					$ 105
Impairment of assets and other charges					105
Impairment of assets and other charges, after tax					79
SCANA | Dominion Energy South Carolina Inc | NND Project
Business Acquisition [Line Items]
Income tax regulatory assets					$ 258
[1]	Includes $105 million of certain property, plant and equipment associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. As a result, Dominion Energy’s Consolidated Statements of Income for the year ended December 31, 2019 include a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges (reflected in the Corporate and Other segment).
[2]	Nonregulated property, plant and equipment, excluding land, will be depreciated on a straight-line basis over the remaining useful lives of such property, primarily ranging from 5 to 78 years.

Acquisitions and Disposition_11

Acquisitions and Dispositions (Results of Operations and Pro Forma Information) (Narrative) (Detail) - SCANA - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Increase in operating revenue	$ 3,600	$ 3,300	$ 3,100
Increase (decrease) in net income	287	277	(1,100)
Merger and integration-related costs			427
Dominion Energy
Business Acquisition [Line Items]
Merger and integration-related costs	$ 31	$ 97	646
Voluntary Retirement Program | Dominion Energy
Business Acquisition [Line Items]
Merger and integration-related costs			427
Other Operations and Maintenance | Dominion Energy
Business Acquisition [Line Items]
Merger and integration-related costs			210
Interest and Related Charges | Dominion Energy
Business Acquisition [Line Items]
Merger and integration-related costs			$ 9

Acquisitions and Disposition_12

Acquisitions and Dispositions (Schedule of Unaudited Pro Forma Information) (Detail) - SCANA $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)$ / shares	[1]
Business Acquisition [Line Items]
Operating revenue | $	$ 15,408
Net income attributable to Dominion Energy | $	$ 3,266
Earnings Per Common Share – Basic | $ / shares	$ 4.04
Earnings Per Common Share – Diluted | $ / shares	$ 4
[1]	Amounts include adjustments for non-recurring costs directly related to the SCANA Combination.

Acquisitions and Disposition_13

Acquisitions and Dispositions (Sale of Interest in Cove Point) (Narrative) (Detail) - Cove Point - USD ($) $ in Billions	1 Months Ended
	Nov. 30, 2020	Dec. 31, 2019	Oct. 31, 2019
Business Acquisition And Dispositions [Line Items]
Ownership interest percentage of limited partner interests	100.00%	25.00%	25.00%
Cash consideration from sale of noncontrolling interest		$ 2.1

Acquisitions and Disposition_14

Acquisitions and Dispositions (Sale of Hope) (Narrative) (Detail) - Ullico Inc - Subsequent Event $ in Millions	1 Months Ended
	Feb. 28, 2022USD ($)
Business Acquisition And Dispositions [Line Items]
Percentage of equity interests expected to be sold	100.00%
Cash consideration from sale of equity interest	$ 690

Acquisitions and Disposition_15

Acquisitions and Dispositions (Sale of Kewaunee) (Narrative) (Detail) - Dominion Energy Kewaunee, Inc - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	May 31, 2021
Business Acquisition And Dispositions [Line Items]
Percentage of equity interests expected to be sold		100.00%
Disposal group, expected to recognized a loss	$ 725
Disposal group, expected to recognized a loss after tax	$ 570

Acquisitions and Disposition_16

Acquisitions and Dispositions (Acquisition of Birdseye) (Narrative) (Detail) - USD ($) $ in Millions		1 Months Ended
		May 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition And Dispositions [Line Items]
Goodwill	[1]		$ 7,405	$ 7,381	$ 7,395
Birdseye
Business Acquisition And Dispositions [Line Items]
Ownership interest acquired		100.00%
Business acquisition, total consideration		$ 46
Business acquisition, cash consideration		28
Business acquisition, fair value of consideration		18
Other deferred charges and other assets, including intangible assets		25
Goodwill		$ 24
[1]	Goodwill amounts do not contain any accumulated impairment losses.

Operating Revenue (Schedule of

Operating Revenue (Schedule of Operating Revenue) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		$ 14,170	$ 13,752	$ 13,745
Other revenues	[1],[2]	(206)	420	656
Total operating revenue		13,964	14,172	14,401
Regulated Electric Sales | Residential
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		4,509	4,833	4,325
Regulated Electric Sales | Commercial
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		3,194	3,102	3,219
Regulated Electric Sales | Industrial
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		748	730	683
Regulated Electric Sales | Government and Other Retail
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		921	868	873
Regulated Electric Sales | Wholesale
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		175	128	176
Nonregulated Electric Sales
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		1,005	823	941
Regulated Gas Sales | Residential
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		1,455	1,283	1,343
Regulated Gas Sales | Commercial
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		527	457	457
Regulated Gas Sales | Other
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		135	88	109
Nonregulated Gas Sales
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		96	174	495
Regulated Gas Transportation and Storage
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		945	801	742
Other Regulated Revenues
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		265	327	252
Other Nonregulated Revenues
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers	[3],[4]	195	138	130
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		7,470	7,661	8,036
Total operating revenue		7,470	7,763	8,108
Other revenues	[1],[4]		102	72
Virginia Electric and Power Company | Regulated Electric Sales | Residential
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		3,366	3,677	3,657
Virginia Electric and Power Company | Regulated Electric Sales | Commercial
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		2,417	2,342	2,712
Virginia Electric and Power Company | Regulated Electric Sales | Industrial
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		367	380	455
Virginia Electric and Power Company | Regulated Electric Sales | Government and Other Retail
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		862	804	823
Virginia Electric and Power Company | Regulated Electric Sales | Wholesale
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		107	90	128
Virginia Electric and Power Company | Nonregulated Electric Sales
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		44	19	15
Virginia Electric and Power Company | Other Regulated Revenues
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		234	299	190
Virginia Electric and Power Company | Other Nonregulated Revenues
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers	[3],[4]	$ 73	$ 50	$ 56
[1]	Includes alternative revenue of $56 million, $119 million and $66 million at Dominion Energy and $44 million, $82 million and $52 million at Virginia Power for years ended December 31, 2021, 2020 and 2019, respectively.
[2]	Includes revenue associated with services provided to discontinued operations of $5 million, $4 million and $6 million for the years ended December 31, 2021, 2020 and 2019, respectively.
[3]	Includes sales which are considered to be goods transferred at a point
[4]	See Notes 9 and 25 for amounts attributable to related parties and affiliates.

Operating Revenue (Schedule o_2

Operating Revenue (Schedule of Operating Revenue) (Parenthetical) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		$ 14,170	$ 13,752	$ 13,745
Gas, Transmission & Storage
Public Utilities General Disclosures [Line Items]
Operating revenue		5	4	6
NGL Midstream | Transferred at a Point in Time
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		34	22	37
Renewable Energy Investment Tax Credits
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		33	20	24
Alternative Revenue Programs
Public Utilities General Disclosures [Line Items]
Other revenues		56	119	66
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		7,470	7,661	8,036
Other revenues	[1],[2]		102	72
Virginia Electric and Power Company | Renewable Energy Investment Tax Credits
Public Utilities General Disclosures [Line Items]
Operating revenue from contracts with customers		21	11	17
Virginia Electric and Power Company | Alternative Revenue Programs
Public Utilities General Disclosures [Line Items]
Other revenues		$ 44	$ 82	$ 52
[1]	Includes alternative revenue of $56 million, $119 million and $66 million at Dominion Energy and $44 million, $82 million and $52 million at Virginia Power for years ended December 31, 2021, 2020 and 2019, respectively.
[2]	See Notes 9 and 25 for amounts attributable to related parties and affiliates.

Operating Revenue (Schedule o_3

Operating Revenue (Schedule of Aggregate Amount of Transaction Price Allocated To Fixed-price Performance Obligations That Unsatisfied At End of Reporting Period And Expected To be Recognized) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 737
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	$ 68
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	$ 66
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 59
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 51
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 45
Revenue, expected to be recognized on multi-year contracts, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2027-01-01
Revenues From Contract With Customer [Line Items]
Revenue, expected to be recognized on multi-year contracts	$ 448
Revenue, expected to be recognized on multi-year contracts, period

Operating Revenue (Schedule o_4

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) (Detail1) $ in Millions	Dec. 31, 2021USD ($)
Revenue From Contract With Customer [Abstract]
Revenue, expected to be recognized on multi-year contracts	$ 737

Operating Revenue (Narrative) (

Operating Revenue (Narrative) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Revenues From Contract With Customer [Line Items]
Revenue recognized from contract liability balances	$ 124	$ 97
Other Current Liabilities and Other Deferred Credits and Other Liabilities
Revenues From Contract With Customer [Line Items]
Contract liability balances	124	130
Virginia Electric and Power Company
Revenues From Contract With Customer [Line Items]
Revenue recognized from contract liability balances	36	24
Virginia Electric and Power Company | Other Current Liabilities and Other Deferred Credits and Other Liabilities
Revenues From Contract With Customer [Line Items]
Contract liability balances	$ 33	$ 36

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Detail) - USD ($) $ in Millions	Nov. 30, 2020	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2017
Income Taxes [Line Items]
Percentage of interest expense adjusted to taxable income			30.00%
State deferred income tax expense (benefit)			$ (19)	$ 72	$ (50)
Current federal income taxes			(117)	(395)	(36)
Taxes charged to common shareholders' equity					215
Income tax expense	$ 336	$ 173	$ 425	$ 83	$ 209
Federal statutory income tax rate			21.00%	21.00%	21.00%	35.00%
Deferred income tax expense (benefit)			$ 425	$ 439	$ 186
Income tax benefit associated with remeasurement of state deferred taxes			(43)	(44)	(119)
Income tax expense attributable to noncontrolling interest				55
Unrecognized tax benefits that would impact effective tax rate		72	72	140	141
Maximum
Income Taxes [Line Items]
Decrease in Unrecognized tax benefits due to settlement negotiations and expiration of statutes of limitations		23	23
Amount that earnings could potentially increase if changes were to occur			9
Virginia Electric and Power Company
Income Taxes [Line Items]
State deferred income tax expense (benefit)			118	7	22
Current federal income taxes			54	435	344
Income tax expense			$ 397	$ 229	$ 264
Federal statutory income tax rate			21.00%	21.00%	21.00%
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits					$ (2)
Deferred income tax expense (benefit)			$ 224	$ (246)	(140)
Income tax benefit associated with remeasurement of state deferred taxes			0	0	0
Virginia Electric and Power Company | Maximum
Income Taxes [Line Items]
Unrecognized tax benefits that would impact effective tax rate					1
SCANA
Income Taxes [Line Items]
Deferred income tax expense (benefit)			194
Discontinued Operations
Income Taxes [Line Items]
Income tax expense			188	(204)	142
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits				5
Unrecognized tax benefits that would impact effective tax rate		$ 33	33
Discontinued Operations | Maximum
Income Taxes [Line Items]
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits					(1)
Continuing Operations
Income Taxes [Line Items]
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits			(34)	(6)	$ 3
Deferred income tax expense (benefit)			(21)
Continuing Operations | Virginia Electric and Power Company
Income Taxes [Line Items]
Deferred income tax expense (benefit)			(16)
Continuing Operations | SCANA
Income Taxes [Line Items]
Increase (Decrease) in tax expense as a result of changes in unrecognized tax benefits			(38)
Cove Point
Income Taxes [Line Items]
Ownership interest percentage of limited partner interests					25.00%
Current federal income taxes					$ 362
Benefit for deferred income taxes					147
Federal tax credits					208
Atlantic Coast Pipeline | Discontinued Operations | Supply Header Project
Income Taxes [Line Items]
Income tax charge				81
Federal
Income Taxes [Line Items]
Deferred income tax expense					$ 48
State
Income Taxes [Line Items]
Income tax benefit associated with remeasurement of state deferred taxes				45
GT&S Transaction
Income Taxes [Line Items]
State deferred income tax expense (benefit)				18
GT&S Transaction | Discontinued Operations
Income Taxes [Line Items]
Income tax benefit related to finalizing income tax returns			14
Income tax expense (benefit) on non-deductible goodwill written off				$ 236
Q-Pipe Group | Discontinued Operations
Income Taxes [Line Items]
Income tax expense (benefit) on non-deductible goodwill written off			$ 36

Income Taxes (Income Tax Expens

Income Taxes (Income Tax Expense for Continuing Operations Including Noncontrolling Interests) (Detail) - USD ($) $ in Millions	Nov. 30, 2020	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current:
Federal			$ (162)	$ (314)	$ (94)
State			45	(81)	58
Total current expense (benefit)			(117)	(395)	(36)
Deferred:
Taxes before operating loss carryforwards, investment tax credits and tax reform			151	12	168
Tax utilization expense of operating loss carryforwards			43	44	119
Investment tax credits			250	311	(51)
State			(19)	72	(50)
Total deferred expense (benefit)			425	439	186
Investment tax credit-gross deferral			121	42	62
Investment tax credit-amortization			(4)	(3)	(3)
Total income tax expense	$ 336	$ 173	425	83	209
Virginia Electric and Power Company
Current:
Federal			67	364	286
State			(13)	71	58
Total current expense (benefit)			54	435	344
Deferred:
Taxes before operating loss carryforwards, investment tax credits and tax reform			145	(226)	(128)
Tax utilization expense of operating loss carryforwards			0	0	0
Investment tax credits			(39)	(27)	(34)
State			118	7	22
Total deferred expense (benefit)			224	(246)	(140)
Investment tax credit-gross deferral			121	42	62
Investment tax credit-amortization			(2)	(2)	(2)
Total income tax expense			$ 397	$ 229	$ 264

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Income Taxes at the U.S. Statutory Federal Income Tax Rate) (Detail)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2017
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	21.00%	21.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	2.60%	2.00%	1.50%
Investment tax credits	(3.20%)	(9.60%)	(11.40%)
Production tax credits	(0.40%)	(0.70%)	(2.10%)
Valuation allowances	0.10%	0.90%	0.50%
Reversal of excess deferred income taxes	(3.20%)	(5.40%)	(3.20%)
State legislative change	(0.70%)	0.00%	0.00%
Write-off of regulatory assets	0.00%	0.00%	21.70%
Change in tax status	0.00%	(1.70%)	(5.50%)
AFUDC—equity	(0.40%)	(0.20%)	(0.20%)
Changes in state deferred taxes associated with assets held for sale	(0.30%)	(3.20%)	0.00%
Absence of tax on noncontrolling interest	(0.10%)	3.80%	(0.20%)
Settlements of uncertain tax positions	(1.20%)	0.00%	0.00%
Employee stock ownership plan deduction	(0.30%)	(0.90%)	(1.40%)
Nondeductible goodwill	0.00%	0.00%	1.80%
Other, net	(0.20%)	(0.10%)	1.50%
Effective tax rate	13.70%	5.90%	24.00%
Virginia Electric and Power Company
Effective Income Tax Computation [Line Items]
U.S. statutory rate	21.00%	21.00%	21.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.60%	4.80%	4.50%
Investment tax credits	(3.00%)	(4.50%)	(2.90%)
Production tax credits	(0.60%)	(0.70%)	(0.70%)
Valuation allowances	0.00%	0.00%	0.00%
Reversal of excess deferred income taxes	(2.10%)	(2.20%)	(3.10%)
State legislative change	(0.70%)	0.00%	0.00%
Write-off of regulatory assets	0.00%	0.00%	0.00%
Change in tax status	0.00%	0.00%	0.00%
AFUDC—equity	(0.50%)	0.00%	0.00%
Changes in state deferred taxes associated with assets held for sale	0.00%	0.00%	0.00%
Absence of tax on noncontrolling interest	0.00%	0.00%	0.00%
Settlements of uncertain tax positions	0.00%	0.00%	0.00%
Employee stock ownership plan deduction	0.00%	0.00%	0.00%
Nondeductible goodwill	0.00%	0.00%	0.00%
Other, net	0.10%	(0.10%)	(0.20%)
Effective tax rate	18.80%	18.30%	18.60%

Income Taxes (Schedule of Defer

Income Taxes (Schedule of Deferred Income Taxes) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred income taxes:
Total deferred income tax assets	$ 3,025	$ 3,285
Total deferred income tax liabilities	9,397	9,069
Total net deferred income tax liabilities	6,372	5,784
Plant and equipment, primarily depreciation method and basis differences	6,017	5,824
Excess deferred income taxes	(1,107)	(1,142)
Unrecovered NND Project costs	508	529
DESC rate refund	(113)	(140)
Toshiba Settlement	(189)	(204)
Nuclear decommissioning	1,114	991
Deferred state income taxes	857	702
Federal benefit of deferred state income taxes	(179)	(147)
Deferred fuel, purchased energy and gas costs	189
Deferred fuel, purchased energy and gas costs		(28)
Pension benefits	362	239
Other postretirement benefits	73	(14)
Loss and credit carryforwards	(1,571)	(1,534)
Valuation allowances	140	155
Partnership basis differences	398	593
Other	(127)	(40)
Total net deferred income tax liabilities	6,372	5,784
Deferred Investment Tax Credits – Regulated Operations	286	169
Total Deferred Taxes and Deferred Investment Tax Credits	6,658	5,953
Virginia Electric and Power Company
Deferred income taxes:
Total deferred income tax assets	1,373	1,204
Total deferred income tax liabilities	4,286	3,832
Total net deferred income tax liabilities	2,913	2,628
Plant and equipment, primarily depreciation method and basis differences	3,327	3,227
Excess deferred income taxes	(629)	(656)
Unrecovered NND Project costs	0	0
DESC rate refund	0	0
Toshiba Settlement	0	0
Nuclear decommissioning	324	303
Deferred state income taxes	420	305
Federal benefit of deferred state income taxes	(88)	(64)
Deferred fuel, purchased energy and gas costs	126
Deferred fuel, purchased energy and gas costs		(34)
Pension benefits	(119)	(105)
Other postretirement benefits	93	76
Loss and credit carryforwards	(537)	(354)
Valuation allowances	6	6
Partnership basis differences	0	0
Other	(10)	(76)
Total net deferred income tax liabilities	2,913	2,628
Deferred Investment Tax Credits – Regulated Operations	270	151
Total Deferred Taxes and Deferred Investment Tax Credits	$ 3,183	$ 2,779

Income Taxes (Schedule of Deduc

Income Taxes (Schedule of Deductible Loss and Credit Carryforwards) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Deductible loss and credit carryforwards [Line Items]
Deductible amount	$ 5,548
Losses, Deferred tax asset	1,604
Losses, Valuation allowance	(140)
Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Losses, Deferred tax asset	537
Losses, Valuation allowance	(6)
Federal
Deductible loss and credit carryforwards [Line Items]
Deductible amount	965
Losses, Deferred tax asset	$ 203
Losses, Expiration Period	2037
Federal | Investment Credits
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	$ 752
Federal | Investment Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	$ 467
Federal | Investment Credits | Earliest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2036
Federal | Investment Credits | Earliest Tax Year | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2036
Federal | Investment Credits | Latest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2041
Federal | Investment Credits | Latest Tax Year | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2041
Federal | Federal Production and Other Credits
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	$ 63
Federal | Federal Production and Other Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax credits, Deferred tax asset	$ 62
Federal | Federal Production and Other Credits | Earliest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2036
Federal | Federal Production and Other Credits | Earliest Tax Year | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2036
Federal | Federal Production and Other Credits | Latest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2041
Federal | Federal Production and Other Credits | Latest Tax Year | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2041
State
Deductible loss and credit carryforwards [Line Items]
Deductible amount	$ 4,583
Losses, Deferred tax asset	243
Losses, Valuation allowance	(50)
State minimum tax credits	$ 214
State | Earliest Tax Year
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2022
State | Latest Tax Year
Deductible loss and credit carryforwards [Line Items]
Losses, Expiration Period	2041
State | Investment and Other Credits
Deductible loss and credit carryforwards [Line Items]
Losses, Valuation allowance	$ (90)
Tax credits, Deferred tax asset	129
State | Investment and Other Credits | Virginia Electric and Power Company
Deductible loss and credit carryforwards [Line Items]
Losses, Valuation allowance	(6)
Tax credits, Deferred tax asset	$ 8
Tax Credits, Expiration Period	2024
State | Investment and Other Credits | Earliest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2022
State | Investment and Other Credits | Latest Tax Year
Deductible loss and credit carryforwards [Line Items]
Tax Credits, Expiration Period	2031

Income Taxes (Unrecognized Tax

Income Taxes (Unrecognized Tax Benefits) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1	$ 167	$ 175	$ 44
Acquired unrecognized tax benefits			129
Increases-prior period positions	48	18
Decreases-prior period positions	(59)	(19)
Increases-current period positions	2	1	9
Settlements with tax authorities	(26)		(7)
Expiration of statutes of limitations	(4)	(8)
Balance at December 31	$ 128	$ 167	175
Virginia Electric and Power Company
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1			2
Settlements with tax authorities			$ (2)

Income Taxes (Unrecognized Ta_2

Income Taxes (Unrecognized Tax Benefits) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Contingency [Line Items]
Acquired unrecognized tax benefits			$ 129
Increases-prior period positions	$ 48	$ 18
Decreases in prior period position	$ 59	$ 19
SCANA
Income Tax Contingency [Line Items]
Acquired unrecognized tax benefits			106
Increases-prior period positions			76
Decreases in prior period position			$ 53

Income Taxes (Earliest Tax Year

Income Taxes (Earliest Tax Year) (Detail)	12 Months Ended
	Dec. 31, 2021
Pennsylvania
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2012
Connecticut
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2018
Virginia
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2018
Utah
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2018
South Carolina
Operation In Major Geographical Areas Tax Year [Line Items]
Earliest Open Tax Year	2018

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Detail) $ in Millions		12 Months Ended
		Dec. 31, 2021USD ($)$ / MMBTU$ / MWh	Dec. 31, 2020USD ($)
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 613	$ 397
Fair Value of Derivative Liabilities		868	486
Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		300	181
Fair Value of Derivative Liabilities		470	405
Fair Value, Measurements, Recurring
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		8,161	6,959
Total liabilities		868	486
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		3,847	3,223
Total liabilities		470	405
Fair Value, Measurements, Recurring | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		282	167
Fair Value of Derivative Liabilities		469	55
Fair Value, Measurements, Recurring | Commodity | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		146	115
Fair Value of Derivative Liabilities		133	29
Fair Value, Measurements, Recurring | Level 3
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		230	110
Total liabilities		8	7
Fair Value, Measurements, Recurring | Level 3 | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Total assets		110	110
Total liabilities		8	7
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		230	110
Fair Value of Derivative Liabilities		8	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		110	110
Fair Value of Derivative Liabilities		8	$ 7
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[1]	54
Fair Value of Derivative Liabilities	[1]	3
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[1]	54
Fair Value of Derivative Liabilities	[1]	$ 3
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Minimum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Minimum | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Minimum | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Minimum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Maximum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	8
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Maximum | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	6
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Maximum | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	4
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Maximum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2]	4
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Weighted Average | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2],[3]	(1)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Weighted Average | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2],[3]	(1)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Weighted Average | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2],[3]	(1)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Natural Gas | Weighted Average | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[1],[2],[3]	(1)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 51
Fair Value of Derivative Liabilities		5
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		51
Fair Value of Derivative Liabilities		$ 5
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Minimum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Minimum | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	(2)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Minimum | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	(3)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Minimum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	(3)
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Maximum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	11
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Maximum | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	11
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Maximum | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	7
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Maximum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	7
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Weighted Average | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2],[3]	2
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Weighted Average | Assets | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2],[3]	2
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Weighted Average | Derivative Financial Instruments, Liabilities | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2],[3]	1
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | FTRs | Weighted Average | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2],[3]	1
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Electricity
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 120
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Electricity | Minimum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	28
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Electricity | Maximum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2]	72
Fair Value, Measurements, Recurring | Level 3 | Discounted Cash Flow | Commodity | Electricity | Weighted Average | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MWh	[2],[3]	43
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Liabilities		$ 5
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Liabilities		$ 5
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Minimum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2]	3
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Minimum | Assets | Price Volatility
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4]	19.00%
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Maximum | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2]	9
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Maximum | Assets | Price Volatility
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4]	27.00%
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Weighted Average | Assets | Market Price
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2],[3]	6
Fair Value, Measurements, Recurring | Level 3 | Option Model | Commodity | Natural Gas | Weighted Average | Assets | Price Volatility
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[3],[4]	24.00%
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Minimum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2]	3
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Minimum | Derivative Financial Instruments, Liabilities | Price Volatility | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4]	19.00%
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Maximum | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2]	9
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Maximum | Derivative Financial Instruments, Liabilities | Price Volatility | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[4]	27.00%
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Weighted Average | Derivative Financial Instruments, Liabilities | Market Price | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price | $ / MMBTU	[2],[3]	6
Fair Value, Measurements, Recurring | Level 3 | Option Model | Physical Options | Natural Gas | Weighted Average | Derivative Financial Instruments, Liabilities | Price Volatility | Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Price volatility (percentage)	[3],[4]	24.00%
[1]	Includes basis.
[2]	Represents market prices beyond defined terms for Levels 1 and 2.
[3]	Averages weighted by volume.
[4]	Represents volatilities unrepresented in published markets.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Detail) - USD ($)	1 Months Ended					3 Months Ended	12 Months Ended
	Mar. 31, 2020	Sep. 30, 2019	May 31, 2019	Mar. 31, 2019	Jan. 31, 2019	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets and other charges (benefits)							$ 195,000,000	$ 2,105,000,000	$ 1,520,000,000
Unrealized gains or losses included in earnings in Level 3 fair value category							0	0	0
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
Corporate Office Building | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, estimated fair value							26,000,000
Nonregulated Retail Software Development | Level 2 | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, estimated fair value							1,000,000
Impairment of Assets and Other Charges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets and other charges (benefits)		$ 26,000,000
Asset impairment charges after tax		19,000,000
Impairment of Assets and Other Charges | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets and other charges (benefits)	$ 751,000,000	17,000,000	$ 62,000,000	$ 346,000,000	$ 160,000,000	$ 76,000,000		127,000,000
Asset impairment charges after tax	$ 559,000,000	$ 12,000,000	$ 46,000,000	$ 257,000,000	$ 119,000,000	$ 56,000,000		$ 94,000,000
Impairment of Assets and Other Charges | Corporate Office Building
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets and other charges (benefits)							16,000,000
Asset impairment charges after tax							12,000,000
Impairment of Assets and Other Charges | Nonregulated Retail Software Development
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets and other charges (benefits)							20,000,000
Asset impairment charges after tax							$ 15,000,000

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		$ 613	$ 397
Derivative Liabilities		868	486
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		300	181
Derivative Liabilities		470	405
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		8,161	6,959
Total liabilities		868	486
Fair Value, Measurements, Recurring | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		3,847	3,223
Total liabilities		470	405
Fair Value, Measurements, Recurring | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5,241	4,648
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	[2]	2,420	2,171
Fair Value, Measurements, Recurring | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	881	629
Fair Value, Measurements, Recurring | Fixed Income | Corporate debt instruments | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	531	348
Fair Value, Measurements, Recurring | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	1,455	1,238
Fair Value, Measurements, Recurring | Fixed Income | Government Securities | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	599	510
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]		47
Cash equivalents and other	[1]	(29)
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	[2]		13
Cash equivalents and other	[2]	(3)
Fair Value, Measurements, Recurring | Foreign Currency Exchange Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		8
Fair Value, Measurements, Recurring | Foreign Currency Exchange Rate | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		8
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		282	167
Derivative Liabilities		469	55
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		146	115
Derivative Liabilities		133	29
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		323	230
Derivative Liabilities		399	431
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		146	66
Derivative Liabilities		337	376
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		5,411	5,188
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		2,510	2,385
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | U.S.
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5,241	4,648
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	[2]	2,420	2,171
Fair Value, Measurements, Recurring | Level 1 | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	199	508
Fair Value, Measurements, Recurring | Level 1 | Fixed Income | Government Securities | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	93	201
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]		32
Cash equivalents and other	[1]	(29)
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	[2]		13
Cash equivalents and other	[2]	(3)
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		2,520	1,661
Total liabilities		860	479
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		1,227	728
Total liabilities		462	398
Fair Value, Measurements, Recurring | Level 2 | Fixed Income | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	881	629
Fair Value, Measurements, Recurring | Level 2 | Fixed Income | Corporate debt instruments | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	531	348
Fair Value, Measurements, Recurring | Level 2 | Fixed Income | Government Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	1,256	730
Fair Value, Measurements, Recurring | Level 2 | Fixed Income | Government Securities | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	506	309
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]		15
Fair Value, Measurements, Recurring | Level 2 | Foreign Currency Exchange Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		8
Fair Value, Measurements, Recurring | Level 2 | Foreign Currency Exchange Rate | Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		8
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		52	57
Derivative Liabilities		461	48
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		36	5
Derivative Liabilities		125	22
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		323	230
Derivative Liabilities		399	431
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		146	66
Derivative Liabilities		337	376
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		230	110
Total liabilities		8	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		110	110
Total liabilities		8	7
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		230	110
Derivative Liabilities		8	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		110	110
Derivative Liabilities		$ 8	$ 7
[1]	Includes investments held in the nuclear decommissioning trusts and rabbi trusts. Excludes $366 million and $340 million of assets at December 31, 2021 and 2020, 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
[2]	Includes investments held in the nuclear decommissioning trusts. Excludes $185 million and $167 million of assets at December 31, 2021 and 2020, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.

Fair Value Measurements (Asse_2

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets measured at fair value using NAV	$ 366	$ 340
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	$ 185	$ 167

Fair Value Measurements (Net Ch

Fair Value Measurements (Net Change in the Assets and Liabilities Measured at Fair Value on a Recurring Basis and Included in the Level 3 Fair Value Category) (Detail) - Commodity - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1,	$ 103	$ (37)	$ 64
Total realized and unrealized gains (losses):
Included in regulatory assets/liabilities	119	140	(90)
Settlements	(10)	33	17
Purchases	0	0	(10)
Sales	0	(1)	6
Transfers out of Level 3	9	0	(3)
Balance at December 31,	222	103	(37)
Virginia Electric and Power Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at January 1,	103	(37)	60
Total realized and unrealized gains (losses):
Included in regulatory assets/liabilities	(1)	140	(88)
Settlements	(4)	33	13
Balance at December 31,	102	103	(37)
Operating Revenue
Total realized and unrealized gains (losses):
Included in earnings	(9)	0	(1)
Electric Fuel and Other Energy-Related Purchases
Total realized and unrealized gains (losses):
Included in earnings	10	(33)	(22)
Electric Fuel and Other Energy-Related Purchases | Virginia Electric and Power Company
Total realized and unrealized gains (losses):
Included in earnings	4	(33)	(22)
Purchased Gas
Total realized and unrealized gains (losses):
Included in earnings	0	0	2
Discontinued Operations
Total realized and unrealized gains (losses):
Included in earnings	$ 0	$ 1	$ 0

Fair Value Measurements (Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Supplemental 364-Day credit facility borrowings			$ 225
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[1],[2]	$ 35,996	31,996
Supplemental 364-Day credit facility borrowings			225
Junior subordinated notes	[3]	1,386	3,411
Carrying Amount | Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[3]	13,753	13,207
Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[1],[2],[4]	40,947	38,773
Supplemental 364-Day credit facility borrowings	[4]		225
Junior subordinated notes	[3],[4]	1,470	3,633
Estimate of Fair Value | Virginia Electric and Power Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	[3],[4]	$ 16,021	$ 16,455
[1]	Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs and discount or premium. At December 31, 2021 and December 31, 2020, the carrying amount includes the valuation of certain fair value hedges associated with fixed rate debt of $2 million and $3 million, respectively.
[2]	Includes amounts classified as held for sale at December 31, 2020, see Note 3.
[3]	Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs, discount or premium.
[4]	Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

Fair Value Measurements (Fina_2

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Parenthetical) (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Valuation of certain fair value hedges associated with fixed rate debt		$ 2	$ 3
Supplemental line of credit facility borrowings expiration period		1 year
364-Day Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument Term	364 days

Derivatives and Hedge Account_3

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet		$ 493	$ 396	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		69	46
Net Amounts		424	350
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet	[2]	271	178
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		35	14
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received			0
Net Amounts		236	164
Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet		153	117	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		13	9
Net Amounts		140	108
Commodity | Over-the-counter | Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet	[2]	110	111
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		8	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received			0
Net Amounts		102	105
Commodity | Exchange
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet		9	49	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		7	24
Net Amounts		2	25
Commodity | Exchange | Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet	[2]	7	1
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		7	1
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received			0
Net Amounts			0
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet		323	230	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		49	13
Net Amounts		274	217
Interest rate | Over-the-counter | Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet	[2]	146	66
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		20	7
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received			0
Net Amounts		126	59
Foreign currency exchange rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet		8
Net Amounts		8
Foreign currency exchange rate | Over-the-counter | Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Assets Presented in the Consolidated Balance Sheet	[2]	8
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments			0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received			0
Net Amounts		$ 8	$ 0
[1]	Excludes $120 million and $1 million of derivative assets at December 31, 2021 and 2020, respectively,
[2]	Excludes $29 million and $3 million of derivative assets at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements.

Derivatives and Hedge Account_4

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Offsetting Assets [Line Items]
Derivative assets, not subject to a master netting or similar arrangement	$ 120	$ 1
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Derivative assets, not subject to a master netting or similar arrangement	$ 29	$ 3

Derivatives and Hedge Account_5

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		$ 868	$ 485	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		69	46
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		432	17
Net Amounts		367	422
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[2]	464	383
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		35	14
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		90
Net Amounts		339	369
Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		95	30	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		13	9
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		54
Net Amounts		28	21
Commodity | Over-the-counter | Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[2]	84	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		8	6
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		54
Net Amounts		22
Commodity | Exchange
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		374	24	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		7	24
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		367
Commodity | Exchange | Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[2]	43	1
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		7	1
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		36
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet		399	431	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		49	13
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral		11	17
Net Amounts		339	401
Interest rate | Over-the-counter | Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Liabilities Presented in the Consolidated Balance Sheet	[2]	337	376
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments		20	7
Net Amounts		$ 317	$ 369
[1]	Excludes $1 million of derivative liabilities at December 31, 2020
[2]	Excludes $6 million and $22 million of derivative liabilities at December 31, 2021 and 2020, respectively, which are not subject to master netting or similar arrangements.

Derivatives and Hedge Account_6

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Offsetting Liabilities [Line Items]
Derivative liabilities, not subject to a master netting or similar arrangement		$ 1
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Derivative liabilities, not subject to a master netting or similar arrangement	$ 6	$ 22

Derivatives and Hedge Account_7

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Detail) - 12 months ended Dec. 31, 2021 kr in Millions, $ in Millions		USD ($)MWhBcf	DKK (kr)
Fixed Price - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity	[1]	34
Fixed Price - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity	[1]	24
Basis - Natural Gas - Current Derivative Contract
Derivative [Line Items]
Volume of derivative activity		156
Basis - Natural Gas - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity		139
Fixed Price - Electricity - Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh		15,000,000
Fixed Price - Electricity - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh		6,000,000
Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh		44,000,000
Financial Transmission Rights - Electricity- Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh		44,000,000
Interest Rate - Current Derivative Contract
Derivative [Line Items]
Derivative payment | $	[2]	$ 1,537
Interest Rate - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Derivative payment | $	[2]	$ 1,000
Foreign Currency Exchange Rate - Current Derivative Contract
Derivative [Line Items]
Derivative payment | kr	[2]		kr 501
Foreign Currency Exchange Rate - Current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Derivative payment | kr	[2]		501
Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative [Line Items]
Volume of derivative activity	[1]	5
Fixed Price - Natural Gas - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity	[1]	5
Basis - Natural Gas - Non-current Derivative Contract
Derivative [Line Items]
Volume of derivative activity		446
Basis - Natural Gas - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of derivative activity		440
Fixed Price - Electricity - Non-current Derivative Contract
Derivative [Line Items]
Volume of electricity | MWh		31
Fixed Price - Electricity - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Volume of electricity | MWh		7,000,000
Interest Rate - Non-current Derivative Contract
Derivative [Line Items]
Derivative payment | $	[2]	$ 9,859
Interest Rate - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Derivative payment | $	[2]	$ 1,750
Foreign Currency Exchange Rate - Non-current Derivative Contract
Derivative [Line Items]
Derivative payment | kr	[2]		4,581
Foreign Currency Exchange Rate - Non-current Derivative Contract | Virginia Electric and Power Company
Derivative [Line Items]
Derivative payment | kr	[2]		kr 4,581
[1]	Includes options.
[2]	Maturity is determined based on final settlement period.

Derivatives and Hedge Account_8

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (358)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(40)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(45)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(2)
Interest rate
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	(358)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (40)
Maximum Term	396 months
Interest rate | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
AOCI After-Tax	$ (45)
Interest rate, Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (2)
Maximum Term	396 months

Derivatives and Hedge Account_9

Derivatives and Hedge Accounting Activities (Narrative) (Detail) - USD ($)	Dec. 31, 2021	Dec. 31, 2020
Derivative Instrument Detail [Abstract]
Derivative instruments designated in fair value hedges	$ 0	$ 0

Derivatives and Hedge Accoun_10

Derivatives and Hedge Accounting Activities (Schedule of Amounts Recorded on Balance Sheet Related to Cumulative Basis Adjustments for Fair Value Hedges) (Detail) - Designated as Hedging Instrument - Fair Value Hedging - Long-term Debt - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments And Hedging Activities Disclosures [Line Items]
Carrying Amount of the Hedged Asset (Liability)	$ (352)	$ (1,153)
Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets (Liabilities)	$ (2)	$ (3)

Derivatives and Hedge Accoun_11

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[1]	$ 122	$ 67
Derivative Asset, Noncurrent	[2]	491	330
Derivative Asset		613	397
Derivative Liabilities, Current	[3]	359	415
Derivative Liabilities, Noncurrent	[4]	509	71
Derivative Liabilities		868	486
Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[5]	76	22
Derivative Asset, Noncurrent	[6]	224	159
Derivative Asset		300	181
Derivative liabilities	[7]	134	390
Derivative Liability, Noncurrent	[8]	336	15
Derivative Liabilities		470	405
Commodity
Derivatives Fair Value [Line Items]
Derivative Asset, Current		103	58
Derivative Asset, Noncurrent		179	109
Derivative Liabilities, Current		304	42
Derivative Liabilities, Noncurrent		165	13
Commodity | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		74	22
Derivative Asset, Noncurrent		72	93
Derivative liabilities		92	28
Derivative Liability, Noncurrent		41	1
Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset, Current		18	9
Derivative Asset, Noncurrent		305	221
Derivative Liabilities, Current		55	373
Derivative Liabilities, Noncurrent		344	58
Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		145	66
Derivative liabilities		42	362
Derivative Liability, Noncurrent		295	14
Foreign currency exchange rate
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		7
Foreign currency exchange rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		7
Designated as Hedging Instrument
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[1]	1
Derivative Asset, Noncurrent	[2]	145	66
Derivative Asset		146	66
Derivative Liabilities, Current	[3]	42	363
Derivative Liabilities, Noncurrent	[4]	295	19
Derivative Liabilities		337	382
Designated as Hedging Instrument | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[5]	1
Derivative Asset, Noncurrent	[6]	145	66
Derivative Asset		146	66
Derivative liabilities		42	362
Derivative Liability, Noncurrent	[8]	295	14
Derivative Liabilities		337	376
Designated as Hedging Instrument | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		145	66
Derivative Liabilities, Current		42	363
Derivative Liabilities, Noncurrent		295	19
Designated as Hedging Instrument | Interest rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		145	66
Derivative liabilities		42	362
Derivative Liability, Noncurrent		295	14
Fair Value - Derivatives not under Hedge Accounting
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[1]	121	67
Derivative Asset, Noncurrent	[2]	346	264
Derivative Asset		467	331
Derivative Liabilities, Current	[3]	317	52
Derivative Liabilities, Noncurrent	[4]	214	52
Derivative Liabilities		531	104
Fair Value - Derivatives not under Hedge Accounting | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current	[5]	75	22
Derivative Asset, Noncurrent	[6]	79	93
Derivative Asset		154	115
Derivative liabilities		92	28
Derivative Liability, Noncurrent	[8]	41	1
Derivative Liabilities		133	29
Fair Value - Derivatives not under Hedge Accounting | Commodity
Derivatives Fair Value [Line Items]
Derivative Asset, Current		103	58
Derivative Asset, Noncurrent		179	109
Derivative Liabilities, Current		304	42
Derivative Liabilities, Noncurrent		165	13
Fair Value - Derivatives not under Hedge Accounting | Commodity | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		74	22
Derivative Asset, Noncurrent		72	93
Derivative liabilities		92	28
Derivative Liability, Noncurrent		41	1
Fair Value - Derivatives not under Hedge Accounting | Interest rate
Derivatives Fair Value [Line Items]
Derivative Asset, Current		17	9
Derivative Asset, Noncurrent		160	155
Derivative Liabilities, Current		13	10
Derivative Liabilities, Noncurrent		49	$ 39
Fair Value - Derivatives not under Hedge Accounting | Foreign currency exchange rate
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		7
Fair Value - Derivatives not under Hedge Accounting | Foreign currency exchange rate | Virginia Electric and Power Company
Derivatives Fair Value [Line Items]
Derivative Asset, Current		1
Derivative Asset, Noncurrent		$ 7
[1]	At December 31, 2021, all current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $63 million is included in other current assets and the remainder is recorded in current assets held for sale.
[2]	A t December 31, 2021, all noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets . At December 31, 2020, $ 330 million is included in other deferred charges and other assets and the remainder is recorded in noncurrent assets held for sale.
[3]	At December 31, 2021, all current derivative liabilities are presented in other current liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $412 million is included in other current liabilities and the remainder is recorded in current liabilities held for sale.
[4]	At December 31, 2021, all noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $71 million is included in other deferred credits and other liabilities and the remainder is recorded in noncurrent liabilities held for sale.
[5]	Current derivative assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets.
[6]	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.
[7]	See Note 25 for amounts attributable to affiliates.
[8]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.

Derivatives and Hedge Accoun_12

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Parenthetical) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Derivatives Fair Value [Line Items]
Current derivative assets	[1]	$ 122	$ 67
Noncurrent derivative assets	[2]	$ 491	330
Other Current Assets
Derivatives Fair Value [Line Items]
Current derivative assets			63
Other Deferred Charges and Other Assets
Derivatives Fair Value [Line Items]
Noncurrent derivative assets			330
Other Current Liabilities
Derivatives Fair Value [Line Items]
Current derivative liabilities			412
Other Deferred Credits and Other Liabilities
Derivatives Fair Value [Line Items]
Noncurrent derivative liabilities			$ 71
[1]	At December 31, 2021, all current derivative assets are presented in other current assets in Dominion Energy’s Consolidated Balance Sheets. At December 31, 2020, $63 million is included in other current assets and the remainder is recorded in current assets held for sale.
[2]	A t December 31, 2021, all noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets . At December 31, 2020, $ 330 million is included in other deferred charges and other assets and the remainder is recorded in noncurrent assets held for sale.

Derivatives and Hedge Accoun_13

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Detail) - Cash Flow Hedges - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[1]	$ 21		$ (320)	$ (145)
Amount of Gain (Loss) Reclassified From AOCI to Income		(61)		(302)	83
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	135		(332)	(255)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[3]	17		(37)	(30)
Amount of Gain (Loss) Reclassified From AOCI to Income		(3)		(2)	(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4]	130		(338)	(259)
Commodity
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[1]				125
Amount of Gain (Loss) Reclassified From AOCI to Income				23	143
Commodity | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(1)	[5]	(4)	(3)
Commodity | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				25	142
Commodity | Discontinued operations
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				2	4
Interest rate
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[1]	21	[6]	(309)	(252)
Amount of Gain (Loss) Reclassified From AOCI to Income		(60)	[6]	(319)	(54)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	135	[6]	(332)	(255)
Interest rate | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[3],[7]	17		(37)	(30)
Amount of Gain (Loss) Reclassified From AOCI to Income	[7]	(3)		(2)	(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[4],[7]	$ 130		(338)	(259)
Interest rate | Discontinued operations
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				(236)	(5)
Interest rate | Interest and Related Charges
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income				(83)	(49)
Foreign currency exchange rate
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives	[1],[8]			(11)	(18)
Amount of Gain (Loss) Reclassified From AOCI to Income	[8]			$ (6)	$ (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 recorded in Dominion Energy’s Consolidated Statements of Income are classified in purchased gas.
[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’s Consolidated Statements of Income are classified in discontinued operations.

Derivatives and Hedge Accoun_14

Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Detail) - Derivatives Not Designated as Hedging Instruments - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ (375)	$ 42	$ (26)
Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2]	(53)	(104)	(45)
Operating Revenue | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2]	(62)	(104)	(45)
Electric Fuel and Other Energy-Related Purchases | Virginia Electric and Power Company
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2]	9
Commodity | Operating Revenue
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(487)	73	41
Commodity | Purchased Gas
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(1)	(20)	(22)
Commodity | Electric Fuel and Other Energy-Related Purchases
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	16	(104)	(46)
Commodity | Discontinued operations
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]		(11)	(2)
Interest rate | Discontinued operations
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]		5
Interest rate | Interest and Related Charges
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ 97	87	$ 3
Foreign currency exchange rate | Discontinued operations
Derivative Instruments Gain Loss [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]		$ 12
[1]	Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion Energy’s Consolidated Statements of Income.
[2]	Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power’s Consolidated Statements of Income.

Earnings Per Share (Calculation

Earnings Per Share (Calculation of Basic and Diluted EPS) (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Net income from continuing operations		$ 2,647	$ 1,583	$ 653
Preferred stock dividends (see Note 19)		(68)	(65)	(17)
Net income attributable to Dominion Energy from continuing operations - Basic		2,579	1,518	636
Dilutive effect of Series A Preferred Stock			(11)	(28)
Net income attributable to Dominion Energy from continuing operations - Diluted		2,579	1,507	608
Net income (loss) from discontinued operations		$ 641	$ (1,984)	$ 705
Average shares of common stock outstanding – Basic		807.8	831	808.8
Net effect of dilutive securities	[1]	0.7		0.1
Average shares of common stock outstanding – Diluted		808.5	831	808.9
EPS from continuing operations - Basic		$ 3.19	$ 1.83	$ 0.79
EPS from discontinued operations - Basic		0.79	(2.39)	0.87
Net income (loss) attributable to Dominion Energy		3.98	(0.56)	1.66
EPS from continuing operations - Diluted		3.19	1.82	0.75
EPS from discontinued operations - Diluted		0.79	(2.39)	0.87
Net income (loss) attributable to Dominion Energy		$ 3.98	$ (0.57)	$ 1.62
[1]	Dilutive securities for 2021 consist primarily of stock expected to be issued to satisfy the obligation under a settlement agreement with the SCDOR (applying the if converted method) as well as forward sales agreements entered into in November 2021 (applying the treasury stock method). See Notes 20 and 23 for additional information.

Investments (Narrative) (Detail

Investments (Narrative) (Detail)		Feb. 22, 2022USD ($)	Nov. 30, 2020USD ($)	Dec. 31, 2021USD ($)	Nov. 30, 2020	Sep. 30, 2020USD ($)	Dec. 31, 2019USD ($)	Oct. 31, 2019	Oct. 31, 2017USD ($)	Sep. 30, 2014mi	Mar. 31, 2019USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Jun. 30, 2021USD ($)	Jul. 31, 2020USD ($)	Mar. 31, 2020USD ($)
Schedule of Equity Method Investments [Line Items]
Earnings from equity method investees												$ 276,000,000	$ 40,000,000	$ 8,000,000
Net income (loss) from discontinued operations including noncontrolling interest	[1],[2]											641,000,000	(1,878,000,000)	716,000,000
Distributions received from investment												328,000,000	102,000,000	38,000,000
Equity method investment goodwill				$ 27,000,000								27,000,000	27,000,000
Income loss from continuing operations before income taxes extraordinary items noncontrolling interest												3,098,000,000	1,411,000,000	869,000,000
Contributions to equity method affiliates												1,021,000,000	148,000,000	209,000,000
Current liabilities													625,000,000
Debt maximum borrowing capacity	[3]			6,000,000,000								6,000,000,000	6,000,000,000
Guarantee liability	[4]			3,923,000,000								3,923,000,000
Retained earnings				5,373,000,000								5,373,000,000	4,189,000,000
Operating revenue from contracts with customers												14,170,000,000	13,752,000,000	13,745,000,000
Income tax expense			$ 336,000,000	173,000,000								425,000,000	83,000,000	209,000,000
Sale of interest in Cove Point														1,862,000,000
Assets				7,269,000,000								7,269,000,000	6,886,000,000
Liabilities				8,673,000,000								8,673,000,000	10,843,000,000
Retail Energy Marketing Operations
Schedule of Equity Method Investments [Line Items]
Assets													63,000,000
Liabilities													15,000,000
Revolving Credit Facility
Schedule of Equity Method Investments [Line Items]
Debt maximum borrowing capacity																$ 6,000,000,000
Finite Lived Equity Method Investment Basis Difference
Schedule of Equity Method Investments [Line Items]
Carrying amount of investment that exceeded share of underlying equity				244,000,000								244,000,000	213,000,000
Unfunded commitments				(4,000,000)								(4,000,000)	(41,000,000)
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Earnings from equity method investees												(20,000,000)	(2,300,000,000)	117,000,000
Net income (loss) from discontinued operations including noncontrolling interest												(20,000,000)	(2,300,000,000)	117,000,000
Contributions to equity method affiliates												965,000,000	107,000,000	186,000,000
Cost to acquire equity method investments																		$ 184,000,000
Equity in earnings (losses) on investments after tax												(14,000,000)	(1,800,000,000)	118,000,000
Atlantic Coast Pipeline | Financial Guarantee
Schedule of Equity Method Investments [Line Items]
Guarantee liability													6,000,000
Atlantic Coast Pipeline | Revolving Credit Facility
Schedule of Equity Method Investments [Line Items]
Debt maximum borrowing capacity									$ 3,400,000,000								$ 1,900,000,000
Credit facility, maturity date									Oct. 31, 2021
Credit facility, amount borrowed													1,800,000,000
Atlantic Coast Pipeline | Revolving Credit Facility | Financial Guarantee | Cumulative Effect, Period of Adoption, Adjustment
Schedule of Equity Method Investments [Line Items]
Retained earnings													48,000,000
Atlantic Coast Pipeline | Other Current Liabilities
Schedule of Equity Method Investments [Line Items]
Current liabilities				$ 113,000,000								$ 113,000,000	1,100,000,000
Atlantic Coast Pipeline | Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage acquired																		5.00%
Percentage ownership in total units																		53.00%
Atlantic Coast Pipeline | DETI
Schedule of Equity Method Investments [Line Items]
Operating revenue from contracts with customers													49,000,000	$ 103,000,000
Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline | Distribution
Schedule of Equity Method Investments [Line Items]
Length of natural gas pipeline (in miles) | mi										600
Duration of contract										20 years
Cove Point
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of general partners					100.00%		25.00%	25.00%
Cove Point | GT&S Transaction
Schedule of Equity Method Investments [Line Items]
Ownership percentage			50.00%		50.00%
JAX LNG LLC | Pivotal LNG
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest sold to noncontrolling interest owners																		50.00%
Blue Racer
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of general partners															50.00%
Additional consideration including interest received in connection with sale											$ 151,000,000
Up-front cash consideration															$ 1,050,000,000
Additional deferred consideration, subject to increase for interest cost effective payable upon purchaser's availability of cash															150,000,000
Fowler Ridge
Schedule of Equity Method Investments [Line Items]
Net payment of long-term power and capacity contract						$ 150,000,000
Contract termination loss													221,000,000
Contract termination loss net of tax													$ 165,000,000
Fowler Ridge | BP Wind Energy North America Inc
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest sold to noncontrolling interest owners						50.00%
Wrangler Retail Gas Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of general partners												20.00%	20.00%	20.00%
Percentage ownership in total units				15.00%								15.00%
Limited partnership interest sale transaction, proceeds received												$ 127,000,000	$ 74,000,000	$ 301,000,000
Initial fair value				$ 23,000,000			$ 75,000,000					23,000,000	13,000,000	75,000,000
Amount of gain from sale												87,000,000	64,000,000	147,000,000
Goodwill write-off												14,000,000		73,000,000
Income tax expense												$ 32,000,000	19,000,000	82,000,000
Wrangler Retail Gas Holdings LLC | Gas Supply, Inc.
Schedule of Equity Method Investments [Line Items]
Ownership interest percentage of general partners												5.00%
Amount of gain from sale												$ 10,000,000
Income tax expense												3,000,000
Sale of interest in Cove Point												33,000,000
Dominion Energy Virginia | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Percentage ownership in total units		50.00%
Agreement entered date		2022-02
Total cash proceeds expected		$ 168,000,000
Expects to recognize gains totaling		150,000,000
Expects to recognize gains totaling, after tax		$ 110,000,000
Cove Point
Schedule of Equity Method Investments [Line Items]
Distributions received from investment												$ 300,000,000	70,000,000
Ownership percentage				50.00%								50.00%
Contributions to equity method affiliates												$ 0	0
Cove Point | Finite Lived Equity Method Investment Basis Difference
Schedule of Equity Method Investments [Line Items]
Equity method investment goodwill				$ 221,000,000								221,000,000	227,000,000
Cove Point | Cove Point
Schedule of Equity Method Investments [Line Items]
Earnings from equity method investees													40,000,000
Distributions received from investment															$ 50,000,000
Percentage of limited partner interest sold							25.00%
Income loss from continuing operations before income taxes extraordinary items noncontrolling interest												528,000,000	511,000,000	$ 471,000,000
Cove Point | Cove Point | GT&S Transaction
Schedule of Equity Method Investments [Line Items]
Percentage of limited partner interest sold					25.00%
Ownership percentage			50.00%		50.00%
Pivotal LNG | Dominion Energy Gas Holdings, LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage acquired																		100.00%
Trading Securities
Schedule of Equity Method Investments [Line Items]
Rabbi trust securities				$ 122,000,000								$ 122,000,000	$ 134,000,000
[1]	Includes income tax expense (benefit) of $188 million, $(204) million and $142 million for the years ended December 31, 2021, 2020 and 2019, respectively
[2]	See Note 9 for amounts attributable to related parties
[3]	This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility 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.
[4]	Excludes Dominion Energy’s guarantees for the new corporate office property and an offshore wind installation vessel discussed in Note 15.

Investments (Equity and Fixed I

Investments (Equity and Fixed Income Securities, Insurance Contracts and Cash Equivalents in Decommissioning Trust Funds) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Investment Holdings [Line Items]
Fixed income securities Fair Value		$ 2,471
Amortized Cost, Total		4,235	$ 3,846
Total Unrealized Gains		3,815	3,081
Total Unrealized Losses	[1]	(100)	(27)
Fair Value, Total		7,950	6,900
Net assets related to pending purchases of securities		35	49
Fair value of securities in an unrealized loss position		883	293
Virginia Electric and Power Company
Investment Holdings [Line Items]
Fixed income securities Fair Value		1,182
Amortized Cost, Total		1,997	1,789
Total Unrealized Gains		1,753	1,429
Total Unrealized Losses	[2]	(16)	(21)
Allowance for Credit Losses, Total		0
Fair Value, Total		3,734	3,197
Net assets related to pending purchases of securities			10
Fair value of securities in an unrealized loss position		425	142
Net assets related to pending sale of securities		5
Common/collective trust funds | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	168	170
Fixed income securities Total Unrealized Gains	[3]	4	5
Fixed income securities Fair Value	[3]	172	175
Common/collective trust funds | Fixed Income | Virginia Electric and Power Company
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	53	58
Fixed income securities Fair Value	[3]	53	58
Equity securities: | U.S.
Investment Holdings [Line Items]
Equity securities Amortized Cost	[4]	1,567	1,756
Equity securities Total Unrealized Gains	[4]	3,734	2,948
Equity securities Total Unrealized Losses	[4]	(13)	(24)
Equity securities Fair Value	[4]	5,288	4,680
Equity securities: | U.S. | Virginia Electric and Power Company
Investment Holdings [Line Items]
Equity securities Amortized Cost	[5]	841	929
Equity securities Total Unrealized Gains	[5]	1,720	1,371
Equity securities Total Unrealized Losses	[5]	(11)	(21)
Equity securities Fair Value	[5]	2,550	2,279
Corporate debt instruments | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	854	572
Fixed income securities Total Unrealized Gains	[3]	32	58
Fixed income securities Total Unrealized Losses	[3]	(5)	(1)
Fixed income securities Fair Value	[3]	881	629
Corporate debt instruments | Fixed Income | Virginia Electric and Power Company
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	517	315
Fixed income securities Total Unrealized Gains	[3]	17	33
Fixed income securities Total Unrealized Losses	[3]	(3)
Fixed income securities Fair Value	[3]	531	348
Government Securities | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	1,382	1,119
Fixed income securities Total Unrealized Gains	[3]	43	66
Fixed income securities Total Unrealized Losses	[3]	(7)	(1)
Fixed income securities Fair Value	[3]	1,418	1,184
Government Securities | Fixed Income | Virginia Electric and Power Company
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total	[3]	584	484
Fixed income securities Total Unrealized Gains	[3]	16	25
Fixed income securities Total Unrealized Losses	[3]	(2)
Fixed income securities Fair Value	[3]	598	509
Insurance Contracts | Fixed Income
Investment Holdings [Line Items]
Fixed income securities Amortized Cost, Total		255	237
Fixed income securities Fair Value		255	237
Cash equivalents and other
Investment Holdings [Line Items]
Cash equivalents and other, Amortized Cost	[6]	9	(8)
Cash equivalents and other, Total Unrealized Gains	[6]	2	4
Cash equivalents and other, Total Unrealized Losses	[6]	(75)	(1)
Cash equivalents and other, Fair Value	[6]	(64)	(5)
Cash equivalents and other | Virginia Electric and Power Company
Investment Holdings [Line Items]
Cash equivalents and other, Total Unrealized Gains	[7]	0	0
Cash equivalents and other, Total Unrealized Losses	[7]	0	0
Cash equivalents and other, Allowance for Credit Losses	[7]	0	0
Cash equivalents and other, Amortized Cost	[7]	2	3
Cash equivalents and other, Fair Value	[7]	$ 2	$ 3
[1]	The fair value of securities in an unrealized loss position was $883 million and $293 million at December 31, 2021 and 2020, respectively.
[2]	The fair value of securities in an unrealized loss position was $425 million and $142 million at December 31, 2021 and 2020, respectively.
[3]	Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability as discussed in Note 2. Changes in allowance for credit losses are included in other income.
[4]	Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.
[5]	Unrealized gains and losses on equity securities are included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2
[6]	Includes pending purchases of securities of $35 million and $49 million at December 31, 2021 and 2020, respectively.
[7]	Includes pending sales of securities of $5 million at December 31, 2021, and pending purchases of securities of $10 million at December 31, 2020

Investments (Portion of Unreali

Investments (Portion of Unrealized Gains and Losses Relates to Equity Securities) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Investment Holdings [Line Items]
Net gains (losses) recognized during the period		$ 1,072	$ 512	$ 919
Less: Net gains recognized during the period on securities sold during the period		(346)	(16)	(80)
Unrealized gains (losses) recognized during the period on securities still held at period end	[1]	726	496	839
Virginia Electric and Power Company
Investment Holdings [Line Items]
Net gains (losses) recognized during the period		552	224	423
Less: Net gains recognized during the period on securities sold during the period		(190)	(6)	(20)
Unrealized gains (losses) recognized during the period on securities still held at period end	[1]	$ 362	$ 218	$ 403
[1]	Included in other income and the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Investments (Fair Value of Fixe

Investments (Fair Value of Fixed Income Securities by Contractual Maturity) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	$ 331
Due after one year through five years	642
Due after five years through ten years	630
Due after ten years	868
Total	2,471
Virginia Electric and Power Company
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	78
Due after one year through five years	335
Due after five years through ten years	361
Due after ten years	408
Total	$ 1,182

Investments (Selected Informati

Investments (Selected Information Regarding Equity and Fixed Income Securities) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales		$ 3,985	$ 4,278	$ 1,712
Realized gains	[1]	441	340	195
Realized losses	[1]	91	297	96
Virginia Electric and Power Company
Schedule of Available-for-sale Securities [Line Items]
Proceeds from sales		1,791	884	858
Realized gains	[1]	228	88	58
Realized losses	[1]	$ 35	$ 68	$ 22
[1]	Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability as discussed in Note 2.

Investments (Investments Under

Investments (Investments Under Equity Method of Accounting) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Investment in equity method affiliates	[1]	$ 2,932	$ 2,934
Cove Point
Schedule of Equity Method Investments [Line Items]
Ownership%		50.00%
Investment in equity method affiliates		$ 2,738	2,784
Description		LNG import/export and storage facility
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Ownership%		53.00%
Investment in equity method affiliates	[2]	$ 0
Description		Gas transmission system
Wrangler Retail Gas Holdings LLC
Schedule of Equity Method Investments [Line Items]
Ownership%	[3]	15.00%
Investment in equity method affiliates		$ 68	74
Description		Nonregulated retail energy marketing
Align RNG, LLC
Schedule of Equity Method Investments [Line Items]
Ownership%	[4]	50.00%
Investment in equity method affiliates	[4]	$ 74	25
Description	[4]	Renewable natural gas
Other Investment
Schedule of Equity Method Investments [Line Items]
Investment in equity method affiliates	[4]	$ 52	$ 51
Ownership%	[4]	various
[1]	Excludes liability to Atlantic Coast Pipeline.
[2]	Dominion Energy’s Consolidated Balance Sheets include a liability associated with its investment in Atlantic Coast Pipeline of $113 million and $1.1 billion at December 31, 2021 and 2020, respectively. See discussion below for additional information.
[3]	Dominion Energy’s ownership interest became 15% in December 2021, following the sale of 5% of its ownership interest. See discussion below.
[4]	Dominion Energy’s unfunded commitment to be made to Align RNG by the end of 2022 was $8 million and $59 million at December 31, 2021 and 2020, respectively. The commitment was fully paid in January 2022.

Investments (Investments Unde_2

Investments (Investments Under Equity Method of Accounting) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Sale of Stock, Percentage of Ownership after Transaction	5.00%
Align RNG, LLC
Schedule of Equity Method Investments [Line Items]
Unfunded Commitments	$ 8	$ 59
Wrangler Retail Gas Holdings LLC
Schedule of Equity Method Investments [Line Items]
Percentage ownership in total units	15.00%
Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Liability associated with its investment	$ 113	$ 1,100
Cove Point
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%

Property, Plant and Equipment (

Property, Plant and Equipment (Property, Plant and Equipment) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Utility:
Generation	$ 23,378	$ 22,697
Transmission	15,430	14,351
Distribution	28,953	27,311
Storage	455	436
Nuclear fuel	2,306	2,283
General and other	4,373	4,130
Plant under construction	3,898	3,350
Total utility	78,793	74,558
Non-jurisdictional - including plant under construction	1,694	1,225
Nonutility:
Nonregulated generation-nuclear	1,773	1,736
Nonregulated generation-solar	2,026	3,268
Nuclear fuel	1,056	1,012
Other-including plant under construction	1,161	1,160
Total nonutility	6,016	7,176
Total property, plant and equipment	86,503	82,959
Virginia Electric and Power Company
Utility:
Generation	17,325	16,769
Transmission	11,760	11,000
Distribution	13,621	12,839
Nuclear fuel	1,702	1,709
General and other	912	845
Plant under construction	2,865	2,338
Total utility	48,185	45,500
Non-jurisdictional - including plant under construction	1,694	1,225
Nonutility:
Other-including plant under construction	11	11
Total property, plant and equipment	$ 49,890	$ 46,736

Property, Plant and Equipment_2

Property, Plant and Equipment (Share of Jointly-Owned Power Stations) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Bath Country Pumped Storage Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	60.00%	[1]
Plant in service	$ 1,063	[1]
Accumulated depreciation	(714)	[1]
Plant under construction	$ 6	[1]
North Anna
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	88.40%	[1]
Plant in service	$ 2,532	[1]
Accumulated depreciation	(1,381)	[1]
Nuclear fuel	730	[1]
Accumulated amortization of nuclear fuel	(576)	[1]
Plant under construction	$ 178	[1]
Clover Power Station
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	50.00%	[1]
Plant in service	$ 610	[1]
Accumulated depreciation	(273)	[1]
Plant under construction	$ 1	[1]
Millstone Unit
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	93.50%	[2]
Plant in service	$ 1,353	[2]
Accumulated depreciation	(522)	[2]
Nuclear fuel	549	[2]
Accumulated amortization of nuclear fuel	(406)	[2]
Plant under construction	$ 127	[2]
Summer Unit
Jointly Owned Utility Plant Interests [Line Items]
Ownership interest	66.70%	[2]
Plant in service	$ 1,522	[2]
Accumulated depreciation	(699)	[2]
Nuclear fuel	603	[2]
Accumulated amortization of nuclear fuel	(387)	[2]
Plant under construction	$ 76	[2]
[1]	Units jointly owned by Virginia Power.
[2]	Unit jointly owned by Dominion Energy.

Schedule of Acquisitions of Sol

Schedule of Acquisitions of Solar Projects (Detail) $ in Millions		1 Months Ended	12 Months Ended
		Mar. 31, 2019MW	Dec. 31, 2021USD ($)MW	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Property Plant And Equipment [Line Items]
Project Cost			$ 101	$ 311	$ 341
Acquisition of Solar Project Greensville in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-08
Date Agreement Closed			2019-08
Project Cost	[1]		$ 127
Date of Commercial Operations			December 2020
MW Capacity | MW			80
Acquisition of Solar Project Myrtle in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-08
Date Agreement Closed			2019-08
Project Cost	[1]		$ 32
Date of Commercial Operations			June 2020
MW Capacity | MW			15
Acquisition of Solar Project Seabrook in South Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-09
Date Agreement Closed			2019-09
Project Cost	[1]		$ 103
Date of Commercial Operations			December 2019
MW Capacity | MW			72
Acquisition of Solar Project Wilkinson in North Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-11
Date Agreement Closed			2019-11
Project Cost	[1]		$ 153
Date of Commercial Operations			December 2019
MW Capacity | MW			74
Acquisition of Solar Project Blackville in South Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-05
Date Agreement Closed			2020-05
Project Cost	[1]		$ 12
Date of Commercial Operations			December 2020
MW Capacity | MW			7
Acquisition of Solar Project Denmark in South Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-05
Date Agreement Closed			2020-05
Project Cost	[1]		$ 14
Date of Commercial Operations			December 2020
MW Capacity | MW			6
Acquisition of Solar Project Yemassee in South Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-05
Date Agreement Closed			2020-08
Project Cost	[1]		$ 17
Date of Commercial Operations			January 2021
MW Capacity | MW			10
Acquisition of Solar Project Trask in South Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-05
Date Agreement Closed			2020-10
Project Cost	[1]		$ 22
Date of Commercial Operations			March 2021
MW Capacity | MW			12
Acquisition of Solar Project Hardin I in Ohio
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-06
Date Agreement Closed			2020-06
Project Cost	[1]		$ 240
Date of Commercial Operations	[2]		Split
MW Capacity | MW			150
Acquisition of Solar Project Madison in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-07
Date Agreement Closed			2020-07
Project Cost	[1]		$ 125
Date of Commercial Operations			Expected 2023
MW Capacity | MW			62
Acquisition of Solar Project Hardin II in Ohio
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-08
Project Cost	[1]		$ 295
Date of Commercial Operations			Expected 2023
MW Capacity | MW			150
Virginia Electric and Power Company
Property Plant And Equipment [Line Items]
Project Cost			$ 75	$ 35	$ 182
MW Capacity | MW		1,292
Virginia Electric and Power Company | Acquisition of Solar Project Gutenberg in North Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2017-09
Date Agreement Closed			2019-06
Project Cost	[1]		$ 142
Date of Commercial Operations			September 2019
MW Capacity | MW			80
Virginia Electric and Power Company | Acquisition of Solar Project Gloucester in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2018-06
Date Agreement Closed			2019-02
Project Cost	[1]		$ 37
Date of Commercial Operations			April 2019
MW Capacity | MW			20
Virginia Electric and Power Company | Acquisition of Solar Project Grasshopper in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered	[3]		2018-08
Date Agreement Closed	[3]		2019-05
Project Cost	[1],[3]		$ 128
Date of Commercial Operations	[3]		October 2020
MW Capacity | MW	[3]		80
Virginia Electric and Power Company | Acquisition of Solar Project Chestnut in North Carolina
Property Plant And Equipment [Line Items]
Date Agreement Entered			2018-08
Date Agreement Closed			2019-05
Project Cost	[1]		$ 127
Date of Commercial Operations			January 2020
MW Capacity | MW			75
Virginia Electric and Power Company | Acquisition of Solar Project Ft. Powhatan in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-06
Date Agreement Closed			2019-06
Project Cost	[1]		$ 267
Date of Commercial Operations			January 2022
MW Capacity | MW			150
Virginia Electric and Power Company | Acquisition of Solar Project Belcher in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered	[4]		2019-06
Date Agreement Closed	[4]		2019-08
Project Cost	[1],[4]		$ 164
Date of Commercial Operations	[4]		June 2021
MW Capacity | MW	[4]		88
Virginia Electric and Power Company | Acquisition of Solar Project Bedford in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-08
Date Agreement Closed			2019-11
Project Cost	[1]		$ 106
Date of Commercial Operations			November 2021
MW Capacity | MW			70
Virginia Electric and Power Company | Acquisition of Solar Project Maplewood in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-10
Date Agreement Closed			2019-10
Project Cost	[1]		$ 185
Date of Commercial Operations			Expected 2022
MW Capacity | MW			120
Virginia Electric and Power Company | Acquisition of Solar Project Rochambeau in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2019-12
Date Agreement Closed			2020-01
Project Cost	[1]		$ 35
Date of Commercial Operations			December 2021
MW Capacity | MW			20
Virginia Electric and Power Company | Acquisition of Solar Project Pumpkinseed in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2020-05
Date Agreement Closed			2020-05
Project Cost	[1]		$ 130
Date of Commercial Operations			Expected 2022
MW Capacity | MW			60
Virginia Electric and Power Company | Acquisition of Solar Project Bookers Mill in Virginia
Property Plant And Equipment [Line Items]
Date Agreement Entered			2021-02
Date Agreement Closed			2021-06
Project Cost	[1]		$ 200
Date of Commercial Operations			Expected 2023
MW Capacity | MW			127
[1]	Includes acquisition costs.
[2]
[3]	Referred to as Butcher Creek once placed in service.
[4]	Referred to as Desper once placed in service.

Schedule of Acquisitions of S_2

Schedule of Acquisitions of Solar Projects (Parenthetical) (Detail) - MW	1 Months Ended
	Jan. 31, 2021	Dec. 31, 2020
Acquisition of Solar Project Hardin I in Ohio
Property Plant And Equipment [Line Items]
Capacity of project commenced commercial operations	53	97

Property, Plant and Equipment_3

Property, Plant and Equipment (Narrative) (Detail) $ in Millions	1 Months Ended			12 Months Ended
	Nov. 30, 2021USD ($)	Mar. 31, 2020USD ($)	Mar. 31, 2019MW	Dec. 31, 2021USD ($)MW	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Aug. 31, 2021USD ($)
Property Plant And Equipment [Line Items]
Property, plant and equipment				$ 59,774	$ 57,848
Impairment of assets and other charges				$ 195	2,105	$ 1,520
Dominion Energy
Property Plant And Equipment [Line Items]
Impairment of assets and other charges					665
Asset impairment charges after tax					293
Impairment of assets and other charges attributable to noncontrolling interest					267
Property, plant and equipment down to estimated fair value					1,400
Wexpro | Natural Gas Gathering Systems
Property Plant And Equipment [Line Items]
Payments to acquire existing natural gas gathering systems	$ 41
Wexpro | Natural Gas Gathering Systems | Colorado, Utah and Wyoming
Property Plant And Equipment [Line Items]
Payments to acquire existing natural gas gathering systems		$ 38
Terra Nova Renewable Partners | Nonregulated Solar Projects | S B L Holdco L L C
Property Plant And Equipment [Line Items]
Percentage of controlling interest				67.00%
Disposal group, total value of consideration				$ 456
Gain (loss) on held for sale				19
Gain (loss) on held for sale, after tax				15
Clearway Energy Inc | Four Brothers And Three Cedars
Property Plant And Equipment [Line Items]
Percentage of controlling interest							50.00%
Disposal group, total value of consideration							$ 335
Gain (loss) on held for sale				229
Gain (loss) on held for sale, after tax				176
Virginia Electric and Power Company
Property Plant And Equipment [Line Items]
Aggregate generation capacity | MW			1,292
Property, plant and equipment				34,656	$ 32,569
Virginia Electric and Power Company | Virginia Regulation
Property Plant And Equipment [Line Items]
Impairment of assets and other charges				318
Acquisition of Solar Project at Schools in Virginia
Property Plant And Equipment [Line Items]
Anticipated projected cost				$ 30
Aggregate generation capacity | MW				15
Project cost				$ 34
Aggregate generation capacity of service solar facilities | MW				17

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets (Goodwill) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	$ 7,381	$ 7,395
Contribution	[2]		(14)
Acquisition	[3]	24
Goodwill, Ending Balance	[1]	7,405	7,381
Corporate and Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]		14
Contribution	[2]		(14)
Operating Segments | Dominion Energy Virginia
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	2,106	2,106
Goodwill, Ending Balance	[1]	2,106	2,106
Operating Segments | Gas Distribution
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	3,512	3,512
Goodwill, Ending Balance	[1]	3,512	3,512
Operating Segments | Dominion Energy South Carolina
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	1,521	1,521
Goodwill, Ending Balance	[1]	1,521	1,521
Operating Segments | Contracted Assets
Goodwill [Roll Forward]
Goodwill, Beginning Balance	[1]	242	242
Acquisition	[3]	24
Goodwill, Ending Balance	[1]	$ 266	$ 242
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	See Note 9 for additional information including amounts reclassified to held for sale at December 31, 2020.
[3]	See Note 3 for more information.

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets (Narrative) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Amortization expense for intangible assets	$ 79	$ 69	$ 95
Acquisition of intangible assets	$ 311
Weighted-average amortization period (years)	7 years
Virginia Electric and Power Company
Goodwill [Line Items]
Amortization expense for intangible assets	$ 31	$ 28	$ 30
Acquisition of intangible assets	$ 276
Weighted-average amortization period (years)	7 years

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets (Components of Intangible Assets) (Detail) - Software, Licenses and Other - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	[1]	$ 1,459	$ 1,295
Accumulated Amortization	[1]	675	530
Virginia Electric and Power Company
Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	[1]	685	482
Accumulated Amortization	[1]	$ 290	$ 148
[1]	Includes $158M of RGGI allowances purchased

Goodwill and Intangible Asset_5

Goodwill and Intangible Assets (Components of Intangible Assets) (Parenthetical) (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Goodwill And Intangible Assets Disclosure [Abstract]
RGGI allowance purchased and consumed	$ 158

Goodwill and Intangible Asset_6

Goodwill and Intangible Assets (Annual Amortization Expense of Intangible Assets) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Finite Lived Intangible Assets [Line Items]
2022	$ 72
2023	58
2024	50
2025	42
2026	28
Virginia Electric and Power Company
Finite Lived Intangible Assets [Line Items]
2022	29
2023	23
2024	20
2025	16
2026	$ 9

Regulatory Assets and Liabili_3

Regulatory Assets and Liabilities (Schedule of Regulatory Assets) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Regulatory assets-current		$ 1,492	$ 699
Regulatory assets-noncurrent		8,643	9,133
Total regulatory assets		10,135	9,832
Dominion Energy South Carolina Inc
Regulatory Assets [Line Items]
Write off of regulatory asset		237
Write off of regulatory asset after tax		178
Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current		850	295
Regulatory assets-noncurrent		4,130	3,509
Total regulatory assets		$ 4,980	3,804
SCANA
Regulatory Assets [Line Items]
Electric service customers over period		20 years
Weighted Average
Regulatory Assets [Line Items]
Weighted average useful life		27 years
Weighted Average | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Weighted average useful life		25 years
Deferred cost of fuel used in electric generation
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	$ 251
Regulatory assets-noncurrent	[1]	409
Deferred cost of fuel used in electric generation | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[2]	131
Regulatory assets-noncurrent	[2]	409
Deferred project costs and DSM programs for gas utilities
Regulatory Assets [Line Items]
Regulatory assets-current	[3]	53	35
Unrecovered Gas Costs
Regulatory Assets [Line Items]
Regulatory assets-current	[4]	191	78
Deferred rider costs for Virginia electric utility
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	72	98
Regulatory assets-noncurrent	[5]	489	311
Ashpond and landfill closure costs
Regulatory Assets [Line Items]
Regulatory assets-current	[6]	193
Ashpond and landfill closure costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[7]	193
Deferred Nuclear Refueling Outage Costs
Regulatory Assets [Line Items]
Regulatory assets-current	[8]	79	53
Deferred Nuclear Refueling Outage Costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[8]	79	53
NND Project Costs
Regulatory Assets [Line Items]
Regulatory assets-current	[9]	138	138
Regulatory assets-noncurrent	[9]	2,226	2,364
PJM transmission rates
Regulatory Assets [Line Items]
Regulatory assets-current	[10]	7	71
PJM transmission rates | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[11]	7	71
Deferred early plant retirement charges
Regulatory Assets [Line Items]
Regulatory assets-current	[12]	226
Regulatory assets-noncurrent	[12]	226
Deferred early plant retirement charges | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[13]	226
Regulatory assets-noncurrent	[13]	226
Other
Regulatory Assets [Line Items]
Regulatory assets-current		170	193
Regulatory assets-noncurrent		609	544
Other | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current		37	33
Regulatory assets-noncurrent		179	164
Derivatives
Regulatory Assets [Line Items]
Regulatory assets-current	[14]	112	33
Derivatives | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[14]	105	40
Unrecognized Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[15]	548	1,363
Deferred Project Costs For Gas Utilities
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[3]	675	632
Interest rate hedges
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[16]	899	1,042
Interest rate hedges | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[17]	604	733
AROs and related funding
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[18]	$ 329	331
Amortization period for deferred costs		105 years
Cost of reacquired debt
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[19]	$ 10	245
Ash pond and landfill closure costs
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[6]	$ 2,223	2,301
Regulatory assets expected collection period commencing year		2021
Ash pond and landfill closure costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-noncurrent	[6]	$ 2,223	2,301
Regulatory assets expected collection period commencing year		2021
Ash pond and landfill closure costs | Minimum
Regulatory Assets [Line Items]
Regulatory assets amounts expected collection period		15 years
Ash pond and landfill closure costs | Minimum | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets amounts expected collection period		15 years
Ash pond and landfill closure costs | Maximum
Regulatory Assets [Line Items]
Regulatory assets amounts expected collection period		18 years
Ash pond and landfill closure costs | Maximum | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets amounts expected collection period		18 years
Deferred Project Costs | Maximum
Regulatory Assets [Line Items]
Amortization period for deferred costs		18 months
Deferred Project Costs | Maximum | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Amortization period for deferred costs		18 months
Deferred rider costs | Virginia Electric and Power Company
Regulatory Assets [Line Items]
Regulatory assets-current	[5]	$ 72	98
Regulatory assets-noncurrent	[5]	$ 489	$ 311
[1]	Reflects deferred fuel expenses for the Virginia, North Carolina and South Carolina jurisdictions of Dominion Energy’s electric generation operations.
[2]	Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s generation operations
[3]	Primarily reflects amounts expected to be collected from or owed to gas customers in Dominion Energy’s service territories associated with current and prospective rider projects, including CEP, PIR and pipeline integrity management. See Note 13 for more information
[4]	Reflects unrecovered gas costs at regulated gas operations, which are recovered through filings with the applicable regulatory authority
[5]	Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information
[6]	Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on
[7]	Primarily reflects legislation enacted in Virginia in 2019 which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on uncollected expenditures once expenditures have been made. See Note 13 for additional information.
[8]	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
[9]	Reflects expenditures by DESC associated with the NND Project, which pursuant to the SCANA Merger Approval Order, will be recovered from DESC electric service customers over a 20-year period ending in 2039. See Note 3 for more information
[10]	Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter.‌
[11]	Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power expects to make to PJM through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter.
[12]	Reflects amounts from the early retirements of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for additional information
[13]	Reflects amounts from the early retirement of certain coal- and oil-fired generating units to be amortized through 2023 in accordance with the settlement of the 2021 Triennial Review. See Note 13 for more information
[14]	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
[15]	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 rate-regulated subsidiaries
[16]	Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 27 years as of December 31, 2021
[17]	Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 25 years as of December
[18]	Represents deferred depreciation and accretion expense related to legal obligations associated with the future retirement of generation, transmission and distribution properties. The AROs primarily relate to DESC’s electric generating facilities, including Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately 105 years
[19]	In 2021, DESC recorded a charge of $237 million ($178 million after-tax) in impairment of assets and other charges, reflected in the Corporate and Other segment, to write-off the balance of a regulatory asset that is no longer probable of recovery under the settlement agreement approved in DESC’s retail electric base rate case.

Regulatory Assets and Liabili_4

Regulatory Assets and Liabilities (Schedule of Regulatory Liabilities) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Oct. 31, 2017
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		$ 986	$ 809
Regulatory liabilities-noncurrent		10,713	10,187
Total regulatory liabilities		11,699	10,996
Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		647	425
Regulatory liabilities-noncurrent		5,740	5,338
Total regulatory liabilities		$ 6,387	5,763
SCANA
Regulatory Liabilities [Line Items]
Regulatory liabilities-current				$ 67
Total regulatory liabilities				$ 1,100
Estimation period of collection to be credited		11 years
Electric service customers over period		20 years
Deferred cost of fuel used in electric generation
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]		58
Deferred cost of fuel used in electric generation | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[2]		58
Regulatory liabilities-noncurrent	[2]		54
Provision for future cost of removal and AROs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	$ 181	183
Regulatory liabilities-noncurrent	[3]	2,331	2,150
Provision for future cost of removal and AROs | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[4]	154	152
Reserve for refunds and rate credits to electric utility customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[5]	420	128
Regulatory liabilities-noncurrent	[5]	448	540
Income taxes refundable through future rates
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[6]	153	124
Regulatory liabilities-noncurrent	[6]	4,260	4,376
Income taxes refundable through future rates | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[7]	63	54
Regulatory liabilities-noncurrent	[7]	2,335	2,404
Monetization of guarantee settlement
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[8]	67	67
Regulatory liabilities-noncurrent	[8]	$ 831	903
Electric service customers over period		20 years
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		$ 110	120
Regulatory liabilities-noncurrent		380	322
Other | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		73	33
Regulatory liabilities-noncurrent		179	181
Commodity derivatives
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[9]	55	9
Nuclear decommissioning trust
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[10]	2,158	1,719
Nuclear decommissioning trust | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[11]	2,158	1,719
Reserve for future credits to Virginia electric customers
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[12]		120
Reserve for future credits to Virginia electric customers | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[13]		120
Overrecovered Other Postretirement Benefit Costs
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[14]	105	111
Unrecognized Pension and Other Postretirement Benefit Costs
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[15]	200	66
Reserve For Refunds To Virginia Electric Customers | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[16]	306
Regulatory liabilities-noncurrent	[16]	25
Provision For Future Cost Of Removal | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-noncurrent	[4]	1,043	980
Derivative Liabilities | Virginia Electric and Power Company
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[9]	$ 51	$ 8
[1]	Reflects deferred fuel expenses for the Virginia, North Carolina and South Carolina jurisdictions of Dominion Energy’s electric generation operations.
[2]	Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s generation operations
[3]	Rates charged to customers by Dominion Energy’s 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
[4]	Rates charged to customers by Virginia Power's 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]	Reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period effective February 2019, in connection with the SCANA Merger Approval Order. See Notes 3 and 13 for more information
[6]	Amounts recorded to pass the effect of reduced income taxes from the 2017 Tax Reform Act to customers in future periods, which will primarily 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]	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
[8]	Reflects amounts to be refunded to DESC electric service customers over a 20-year period ending in 2039 associated with the monetization of a bankruptcy settlement agreement. See Note 3 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]	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, as applicable) for the future decommissioning of Dominion Energy’s utility nuclear generation stations, in excess of the related AROs.
[11]	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power’s utility nuclear generation stations, in excess of the related AROs
[12]	Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information.
[13]	Represents a reserve related to the expected use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information
[14]	Reflects a regulatory liability for the collection of postretirement benefit costs allowed in rates in excess of expense incurred.
[15]	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 rate-regulated subsidiaries
[16]	Reflects amounts to be refunded to jurisdictional retail electric customers in Virginia associated with the settlement of the 2021 Triennial Review. See Note 13 for additional information

Regulatory Assets and Liabili_5

Regulatory Assets and Liabilities (Narrative) (Detail) $ in Billions	12 Months Ended
	Dec. 31, 2021USD ($)
Public Utilities General Disclosures [Line Items]
Regulatory assets not expect to earn return	$ 4.4
Period for which expenditures are expected to be recovered	2 years
Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Regulatory assets not expect to earn return	$ 3
Period for which expenditures are expected to be recovered	2 years

Regulatory Matters (Narrative)

Regulatory Matters (Narrative) (Detail) $ in Millions

Nov. 01, 2021USD ($)

Feb. 28, 2022USD ($)

Jan. 31, 2022USD ($)

Dec. 31, 2021USD ($)

Nov. 30, 2021USD ($)

Oct. 31, 2021USD ($)

Sep. 30, 2021USD ($)MW

Aug. 31, 2021USD ($)

Jul. 31, 2021USD ($)

Jun. 30, 2021USD ($)ProjectComponent

May 31, 2021USD ($)

Apr. 30, 2021USD ($)

Mar. 31, 2021USD ($)

Feb. 28, 2021USD ($)

Jan. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Sep. 30, 2020USD ($)mi

Aug. 31, 2020USD ($)

Jul. 31, 2020USD ($)MW

Apr. 30, 2020USD ($)MW

Mar. 31, 2020USD ($)

Jan. 31, 2020

Sep. 30, 2019USD ($)

May 31, 2019USD ($)

Mar. 31, 2019USD ($)

Jan. 31, 2019USD ($)

Nov. 30, 2013kVmi

Dec. 31, 2011

Mar. 31, 2021USD ($)

Dec. 31, 2022USD ($)

Mar. 31, 2022USD ($)

Dec. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Dec. 31, 2008

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

$ 195

$ 2,105

$ 1,520

Other operations and maintenance

3,734

3,685

3,790

Regulatory assets

$ 10,135

$ 9,832

10,135

9,832

Regulatory liabilities

986

$ 809

986

809

Impairment of Assets and Other Charges

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

$ 26

Impairment of assets and other charges after tax

19

Target to Reach by End of 2025

Public Utilities General Disclosures [Line Items]

Energy efficiency target percentage. based on energy savings from 2019 baseline

5.00%

Virginia Regulation

Public Utilities General Disclosures [Line Items]

Percentage of electric energy excluding existing nuclear generation and certain new carbon resources

100.00%

Cap on revenue reductions in the first triennial

$ 50

North Carolina Regulation | Pipeline Integrity and Safety Program

Public Utilities General Disclosures [Line Items]

Total revenue requirement

$ 34

Increase (decrease) in revenue requirement

1

South Carolina Regulation | South Carolina Electric Base Rate Case

Public Utilities General Disclosures [Line Items]

Return of equity percentage

5.90%

Increase (decrease) in revenue requirement

$ 62

$ 178

Approved return on equity percentage

9.50%

10.25%

Increase (decrease) in revenue requirement, percentage

7.75%

Public utilities, requested rate increase amortization of certain excess deferred income taxes

$ 36

Public utilities, retail electric customer balance

15

Public utilities energy efficiency upgrades and critical health and safety repairs

$ 15

Regulatory assets

237

237

South Carolina Regulation | South Carolina Electric Base Rate Case | Impairment of Assets and Other Charges (Benefits)

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

249

Impairment of assets and other charges after tax

187

South Carolina Regulation | South Carolina Electric Base Rate Case | Other Income

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

18

Impairment of assets and other charges after tax

14

Ohio Regulation

Public Utilities General Disclosures [Line Items]

Percentage of debt rate on capital investments

6.50%

Ohio Regulation | PIR Program

Public Utilities General Disclosures [Line Items]

Return of equity percentage

3.00%

3.00%

Percentage of pipeline system replaced

25.00%

Projected capital investment

$ 200

Period for cost cap

5 years

Last date of investment

Dec. 31, 2026

Total estimated cost

$ 178

178

Total cumulative estimated cost

$ 2,000

Approved annual revenue required

243

Ohio Regulation | C E P Program

Public Utilities General Disclosures [Line Items]

Total estimated cost

99

99

137

Total cumulative estimated cost

957

957

Proposed revenue requirement

119

Ohio Regulation | UEX Rider

Public Utilities General Disclosures [Line Items]

Increase (decrease) in revenue requirement

$ 20

Public utilities, under-recovered accumulated bad debt expense

7

Ohio Regulation | Forecast | UEX Rider

Public Utilities General Disclosures [Line Items]

Recovery of bad debt expense

$ 13

Virginia Electric and Power Company

Public Utilities General Disclosures [Line Items]

Proposed cost of project

$ 3,900

$ 1,400

Other operations and maintenance

1,460

1,472

$ 1,376

Regulatory assets

4,980

3,804

4,980

3,804

Regulatory liabilities

647

425

647

425

Virginia Electric and Power Company | Impairment of Assets and Other Charges

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

$ 751

17

$ 62

$ 346

$ 160

76

127

Impairment of assets and other charges after tax

$ 559

12

$ 46

$ 257

$ 119

$ 56

94

Virginia Electric and Power Company | Income Payment Program

Public Utilities General Disclosures [Line Items]

Total revenue requirement

$ 93

Virginia Electric and Power Company | Grid Transformation And Security Act | Impairment of Assets and Other Charges

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

130

Impairment of assets and other charges (benefits)

130

Impairment of assets and other charges (benefits) after tax

97

Virginia Electric and Power Company | Grassfields Solar Norge Solar And Sycamore Solar

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

82

Proposed cost of project

$ 170

Virginia Electric and Power Company | Virginia Power North Carolina Fuel Filing

Public Utilities General Disclosures [Line Items]

Fuel Component of Electric Rates

$ 26

Virginia Electric and Power Company | Utility-scale Solar

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

661

Virginia Electric and Power Company | Energy Storage

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

70

Virginia Electric and Power Company | CVOW Commercial Project

Public Utilities General Disclosures [Line Items]

Estimated cost

$ 1,100

Virginia Electric and Power Company | Virginia Regulation

Public Utilities General Disclosures [Line Items]

Rate reduction

50

Impairment of assets and other charges

318

Increase (decrease) in revenue requirement

330

Refund to customer over 6 month period

255

Refund to customer three years

75

Increase (Decrease) Over Previous Year

309

Virginia Electric and Power Company | Virginia Regulation | Impairment of Assets and Other Charges

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

318

Impairment of assets and other charges after tax

237

Virginia Electric and Power Company | Virginia Regulation | Operating Revenue

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

356

Impairment of assets and other charges after tax

265

Virginia Electric and Power Company | Virginia Regulation | Regulatory Asset Associated with Early Retirements

Public Utilities General Disclosures [Line Items]

Impairment of assets and other charges

549

Impairment of assets and other charges after tax

409

Virginia Electric and Power Company | Virginia Regulation | Base Rate Case

Public Utilities General Disclosures [Line Items]

Return of equity percentage

10.42%

10.85%

CVOWP project investment elected for CCRO to offset available revenues

$ 26

Requested authorized return on equity percentage

10.80%

Increase (decrease) in revenue requirement

$ 50

Authorized return percentage

9.35%

Virginia Electric and Power Company | Virginia Regulation | Annual Fuel Factor

Public Utilities General Disclosures [Line Items]

Total revenue requirement

$ 1,400

Rate year beginning

2021-07

Estimated under-recovered balances

$ 72

Virginia Electric and Power Company | Virginia Regulation | Grid Transformation And Security Act

Public Utilities General Disclosures [Line Items]

Number of electric distribution grid transformation projects | Project

14

Number Of Electric Distribution Grid Transformation Projects Components | Component

6

Proposed cost of project

$ 667

Other operations and maintenance

110

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

Public Utilities General Disclosures [Line Items]

Miles of Lines | mi

7

Type of Line | kV

500

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

Public Utilities General Disclosures [Line Items]

Miles of Lines | mi

20

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

Public Utilities General Disclosures [Line Items]

Type of Line | kV

230

Virginia Electric and Power Company | Virginia Regulation | Solar And Onshore Wind | Target to Reach by End of 2035

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

16,100

Virginia Electric and Power Company | Virginia Regulation | Utility-scale Solar | Target to Reach by End of 2035 | Maximum

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

15,000

Virginia Electric and Power Company | Virginia Regulation | Utility-scale Solar | Target to Reach by End of 2024

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

3,000

Virginia Electric and Power Company | Virginia Regulation | Small-scale Solar | Target to Reach by End of 2035

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

1,100

Virginia Electric and Power Company | Virginia Regulation | Energy Storage | Target to Reach by End of 2035

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

2,700

Virginia Electric and Power Company | Virginia Regulation | Pumped Storage | Target to Reach by End of 2035 | Maximum

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

800

Virginia Electric and Power Company | Virginia Regulation | Offshore Wind Facility | Target to Reach by End of 2035 | Maximum

Public Utilities General Disclosures [Line Items]

Targeted capacity provided by legislation | MW

5,200

Constructed by utility capacity | MW

3,000

Virginia Electric and Power Company | Virginia Regulation | Offshore Wind Facility | Target to Reach by End of 2035 | Minimum

Public Utilities General Disclosures [Line Items]

Constructed by utility capacity | MW

2,500

Virginia Electric and Power Company | North Carolina Regulation

Public Utilities General Disclosures [Line Items]

Approved return on equity percentage

9.75%

Virginia Electric and Power Company | North Carolina Regulation | Base Rate Case

Public Utilities General Disclosures [Line Items]

Return of equity percentage

10.75%

Increase (decrease) in revenue requirement

$ 24

$ 27

Authorized return percentage

9.90%

Percentage of earned return

7.52%

PSNC | Base Rate Case

Public Utilities General Disclosures [Line Items]

Increase (decrease) in revenue requirement

$ 53

Authorized return percentage

9.70%

Percentage of earned return

10.25%

Increase (decrease) in revenue requirement in connection with federal and state income tax reductions

$ 42

Increase (decrease) in revenue requirement in connection with federal and state income tax reductions, initial rate year

6

$ 4

Increase (decrease) in revenue requirement in connection with federal and state income tax reductions, second rate year

25

23

Increase (decrease) in revenue requirement in connection with federal and state income tax reductions, third through fifth rate year

$ 27

$ 26

Return on equity percentage

9.60%

Increase in gas cost

$ 29

Recovery amount of operation and maintenance costs

$ 106

Recovery period of operation and maintenance costs

4 years

PSNC | North Carolina Regulation | Rider D

Public Utilities General Disclosures [Line Items]

Rate year beginning

2021-12

2021-10

Increase in gas cost

$ 49

$ 61

Increase in customers deferred account

$ 15

Dominion Energy South Carolina Inc | South Carolina Regulation | Rider DSM

Public Utilities General Disclosures [Line Items]

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

$ 43

$ 48

Application date

2021-01

Approval date

2021-04

Dominion Energy South Carolina Inc | South Carolina Regulation | Rider DSM | Subsequent Event

Public Utilities General Disclosures [Line Items]

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

$ 60

Dominion Energy South Carolina Inc | South Carolina Regulation | Gas Rate Case

Public Utilities General Disclosures [Line Items]

Total revenue requirement

$ 424

426

Increase (decrease) in revenue requirement

$ 9

Approved increase in revenue required

$ 7

Dominion Energy South Carolina Inc | South Carolina Regulation | Cost of Fuel

Public Utilities General Disclosures [Line Items]

Rate year beginning

2021-05

Application date

2021-02

Approval date

2021-04

Increase decrease in annual base fuel component recoveries

$ 36

Dominion Energy South Carolina Inc | South Carolina Regulation | Cost of Fuel | Subsequent Event

Public Utilities General Disclosures [Line Items]

Rate year beginning

2022-05

Application date

2022-02

Increase decrease in annual base fuel component recoveries

$ 143

Regulatory liabilities

$ 66

Hope Gas Inc | West Virginia Regulation | PREP

Public Utilities General Disclosures [Line Items]

Rate year beginning

2021-11

Application date

2021-10

Projected capital investment

$ 54

Amount of cost recovery

$ 9

$ 34

Hope Gas Inc | West Virginia Regulation | West Virginia Base Rate Case

Public Utilities General Disclosures [Line Items]

Return of equity percentage

10.25%

Increase (decrease) in revenue requirement

$ 28

Approved return on equity percentage

9.54%

9.45%

Approved increase in revenue required

$ 13

Public Utilities distribution infrastructure gathering assets | mi

2,000

Hope Gas Inc | West Virginia Regulation | Forecast | PREP

Public Utilities General Disclosures [Line Items]

Projected capital investment

$ 56

Questar Gas Company | Utah Regulation

Public Utilities General Disclosures [Line Items]

Increase in gas cost

$ 83

$ 43

$ 29

Regulatory Matters - Schedule o

Regulatory Matters - Schedule of Additional Significant Riders Associated with Virginia Power Projects (Detail) - Virginia Electric and Power Company $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Rider BW
Public Utilities General Disclosures [Line Items]
Application Date	2021-10
Approval Date	Pending
Rate Year Beginning	2023-09
Total Revenue Requirement (millions)	$ 120
Increase (decrease) in revenue requirement	$ (25)
Rider B
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	February 2022
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 16
Increase (decrease) in revenue requirement	$ (8)
Rider E
Public Utilities General Disclosures [Line Items]
Application Date	2021-01
Approval Date	September 2021
Rate Year Beginning	2021-11
Total Revenue Requirement (millions)	$ 67
Increase (decrease) in revenue requirement	$ (18)
Rider B
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 24
Increase (decrease) in revenue requirement	$ (8)
Rider GV
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	December 2021
Rate Year Beginning	2023-04
Total Revenue Requirement (millions)	$ 127
Increase (decrease) in revenue requirement	$ (15)
Rider BW
Public Utilities General Disclosures [Line Items]
Application Date	2021-10
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 145
Increase (decrease) in revenue requirement	$ 32
Rider R
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	Pending
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 59
Increase (decrease) in revenue requirement	$ 1
Rider S
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	February 2022
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 192
Increase (decrease) in revenue requirement	$ (2)
Rider W
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 120
Increase (decrease) in revenue requirement	$ 14
Rider US-2
Public Utilities General Disclosures [Line Items]
Application Date	2020-10
Approval Date	July 2021
Rate Year Beginning	2021-09
Total Revenue Requirement (millions)	$ 9
Rider CCR
Public Utilities General Disclosures [Line Items]
Application Date	2021-02
Approval Date	October 2021
Rate Year Beginning	2021-12
Total Revenue Requirement (millions)	$ 216
Rider US-2
Public Utilities General Disclosures [Line Items]
Application Date	2021-10
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 11
Increase (decrease) in revenue requirement	$ 2
Rider BW
Public Utilities General Disclosures [Line Items]
Application Date	2020-10
Approval Date	July 2021
Rate Year Beginning	2021-09
Total Revenue Requirement (millions)	$ 113
Increase (decrease) in revenue requirement	$ 14
Rider CE
Public Utilities General Disclosures [Line Items]
Application Date	2020-10
Approval Date	April 2021
Rate Year Beginning	2021-06
Total Revenue Requirement (millions)	$ 10
Rider CE
Public Utilities General Disclosures [Line Items]
Application Date	2021-09
Approval Date	Pending
Rate Year Beginning	2022-05
Total Revenue Requirement (millions)	$ 71
Increase (decrease) in revenue requirement	$ 61
Rider E
Public Utilities General Disclosures [Line Items]
Application Date	2022-01
Approval Date	Pending
Rate Year Beginning	2022-11
Total Revenue Requirement (millions)	$ 101
Increase (decrease) in revenue requirement	$ 34
Rider US-3
Public Utilities General Disclosures [Line Items]
Application Date	2020-07
Approval Date	March 2021
Rate Year Beginning	2021-06
Total Revenue Requirement (millions)	$ 38
Increase (decrease) in revenue requirement	$ 10
Rider GT
Public Utilities General Disclosures [Line Items]
Application Date	2021-08
Approval Date	Pending
Rate Year Beginning	2022-06
Total Revenue Requirement (millions)	$ 56
Rider GV
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 153
Increase (decrease) in revenue requirement	$ 21
Rider GV
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	December 2021
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 142
Increase (decrease) in revenue requirement	$ (11)
Rider OSW
Public Utilities General Disclosures [Line Items]
Application Date	2021-11
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 79
Rider R
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 58
Increase (decrease) in revenue requirement	$ 14
Rider US-3
Public Utilities General Disclosures [Line Items]
Application Date	2021-08
Approval Date	Pending
Rate Year Beginning	2022-06
Total Revenue Requirement (millions)	$ 50
Increase (decrease) in revenue requirement	$ 12
Rider US-4
Public Utilities General Disclosures [Line Items]
Application Date	2020-07
Approval Date	March 2021
Rate Year Beginning	2021-06
Total Revenue Requirement (millions)	$ 10
Increase (decrease) in revenue requirement	$ 3
Rider R
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	Pending
Rate Year Beginning	2023-04
Total Revenue Requirement (millions)	$ 55
Increase (decrease) in revenue requirement	$ (4)
Rider US-4
Public Utilities General Disclosures [Line Items]
Application Date	2021-08
Approval Date	Pending
Rate Year Beginning	2022-06
Total Revenue Requirement (millions)	$ 15
Increase (decrease) in revenue requirement	$ 5
Rider RGGI
Public Utilities General Disclosures [Line Items]
Approval Date	August 2021
Rate Year Beginning	2021-09
Total Revenue Requirement (millions)	$ 168
Rider RGGI
Public Utilities General Disclosures [Line Items]
Application Date	2021-12
Approval Date	Withdrawal pending
Rider RPS
Public Utilities General Disclosures [Line Items]
Application Date	2020-12
Approval Date	July 2021
Rate Year Beginning	2021-08
Total Revenue Requirement (millions)	$ 13
Rider RPS
Public Utilities General Disclosures [Line Items]
Application Date	2021-12
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 140
Increase (decrease) in revenue requirement	$ 127
Rider S
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 194
Increase (decrease) in revenue requirement	$ (1)
Rider S
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	February 2022
Rate Year Beginning	2023-04
Total Revenue Requirement (millions)	$ 191
Increase (decrease) in revenue requirement	$ (1)
Rider SNA
Public Utilities General Disclosures [Line Items]
Application Date	2021-10
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 109
Rider T1
Public Utilities General Disclosures [Line Items]
Application Date	2021-05
Approval Date	August 2021
Rate Year Beginning	2021-09
Total Revenue Requirement (millions)	$ 874
Increase (decrease) in revenue requirement	$ (190)
Rider U
Public Utilities General Disclosures [Line Items]
Application Date	2020-06
Approval Date	February 2021
Rate Year Beginning	2021-04
Total Revenue Requirement (millions)	$ 80
Increase (decrease) in revenue requirement	$ 28
Rider U
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	Pending
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 96
Increase (decrease) in revenue requirement	$ 16
Rider W
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Approval Date	February 2022
Rate Year Beginning	2022-04
Total Revenue Requirement (millions)	$ 121
Increase (decrease) in revenue requirement	$ 1
DSM Riders [Member]
Public Utilities General Disclosures [Line Items]
Application Date	2020-12
Approval Date	September 2021
Rate Year Beginning	2021-10
Total Revenue Requirement (millions)	$ 74
Increase (decrease) in revenue requirement	$ 14
DSM Riders [Member]
Public Utilities General Disclosures [Line Items]
Application Date	2021-12
Approval Date	Pending
Rate Year Beginning	2022-09
Total Revenue Requirement (millions)	$ 91
Increase (decrease) in revenue requirement	$ 17

Regulatory Matters - Schedule_2

Regulatory Matters - Schedule of Additional Significant Riders Associated with Virginia Power Projects (Parenthetical) (Detail) $ in Millions	1 Months Ended						12 Months Ended
	Dec. 31, 2021USD ($)program	Oct. 31, 2021USD ($)	Jun. 30, 2021USD ($)	May 31, 2021USD ($)	Dec. 31, 2020USD ($)program	Jun. 30, 2020USD ($)	Dec. 31, 2021USD ($)
Public Utilities General Disclosures [Line Items]
Number of new demand response programs | program					1
Rider SNA | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total revenue requirement							$ 109
Rider T1 | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total revenue requirement							874
Rider T1 | Virginia Regulation | Virginia Electric and Power Company | Operating Segments
Public Utilities General Disclosures [Line Items]
Total revenue requirement				$ 381
Rider T1 | Virginia Regulation | Virginia Electric and Power Company | Operating Segments | Transmission Component Of Virginia Powers
Public Utilities General Disclosures [Line Items]
Total revenue requirement				$ 493
Rider U | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Total revenue requirement							$ 80
Rider U | Virginia Regulation | Virginia Electric and Power Company | Fifth Phase
Public Utilities General Disclosures [Line Items]
Projected capital investment						$ 36
Rider U | Virginia Regulation | Virginia Electric and Power Company | Previous Phase
Public Utilities General Disclosures [Line Items]
Projected capital investment			$ 61			$ 44
Rider U | Virginia Regulation | Virginia Electric and Power Company | Six Phase
Public Utilities General Disclosures [Line Items]
Projected capital investment			$ 35
Rider C4A | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Amount of cost cap recovery	$ 140				$ 162
Nuclear Life Extension Program | Rider SNA | Virginia Regulation | Virginia Electric and Power Company
Public Utilities General Disclosures [Line Items]
Approved annual revenue required		$ 1,200
Energy Efficiency Program | Virginia Regulation | Virginia Electric and Power Company | Operating Segments
Public Utilities General Disclosures [Line Items]
Number of new energy efficiency programs | program	9
Period for cost cap					5 years
Energy Efficiency Program | Rider C4A | Virginia Regulation | Virginia Electric and Power Company | Operating Segments
Public Utilities General Disclosures [Line Items]
Number of new energy efficiency programs | program					10

Regulatory Matters - Summary of

Regulatory Matters - Summary of Virginia Power Electric Transmission Project Applied (Detail) - Virginia Electric and Power Company $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)kVmi
Bristers-Ladysmith Rebuild Project in the counties of Fauquier, Stafford, Spotsylvania, and Caroline, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2020-05
Approval Date	2021-02
Type of Line | kV	500
Miles of Lines | mi	37
Cost Estimate | $	$ 110
Relocate and replace a transmission line underground between the Tysons substation and the future Spring Hill substation
Public Utilities General Disclosures [Line Items]
Application Date	2020-09
Approval Date	2021-06
Type of Line | kV	230
Cost Estimate | $	$ 30
Rebuild an Existing Transmission Line and Install New Line Adjacent thereto in Counties of New Kent, King William, King and Queen Essex and Richmond, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2020-10
Approval Date	2021-12
Type of Line | kV	230
Miles of Lines | mi	41
Cost Estimate | $	$ 100
Rebuild Clubhouse - Dry Bread Line and Dry Bread Lakeview Line in Greensville County, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2020-11
Approval Date	2021-07
Type of Line | kV	230
Miles of Lines | mi	13
Cost Estimate | $	$ 20
Rebuild transmission lines and related projects in the Counties of York and James City and the City of Williamsburg, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-01
Approval Date	2021-09
Type of Line | kV	230
Miles of Lines | mi	11
Cost Estimate | $	$ 30
Elmont-Ladysmith rebuild and related projects in the Counties of Hanover and Caroline, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-04
Type of Line | kV	500
Miles of Lines | mi	26
Cost Estimate | $	$ 95
Approval Date	Pending
Beaumeade-Belmont reconductor and rebuild projects in the County of Loudoun, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-05
Type of Line | kV	230
Miles of Lines | mi	7
Cost Estimate | $	$ 15
Approval Date	February 2022
Rebuild transmission lines and related projects in the City of Staunton and County of Augusta, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-11
Type of Line | kV	230
Miles of Lines | mi	21
Cost Estimate | $	$ 45
Approval Date	Pending
Extension to Cloud Switching Station and Easters Switching Station in the County of Mecklenburg, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-06
Type of Line | kV	230
Miles of Lines | mi	15
Cost Estimate | $	$ 105
Approval Date	February 2022
Build new DTC substation and line loop in the County of Loudoun, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2021-12
Type of Line | kV	230
Miles of Lines | mi	1
Cost Estimate | $	$ 105
Approval Date	Pending
Build new Aviator substation and line loop in the County of Loudoun, Virginia
Public Utilities General Disclosures [Line Items]
Application Date	2022-02
Type of Line | kV	230
Miles of Lines | mi	1
Cost Estimate | $	$ 80
Approval Date	Pending

Asset Retirement Obligations (C

Asset Retirement Obligations (Changes to AROs) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020
Asset Retirement Obligations [Line Items]
AROs, Beginning balance		$ 5,583	[1]	$ 5,184
Obligations incurred during the period		31		67
Obligations settled during the period		(165)		(114)
Revisions in estimated cash flows		(151)	[2]	228	[3]
Accretion		224		218
Sale of non-wholly-owned nonregulated solar facilities		(49)
AROs, Ending balance	[1]	5,473		5,583
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
AROs, Beginning balance		3,820		3,581
Obligations incurred during the period		26		48
Obligations settled during the period		(131)		(85)
Revisions in estimated cash flows		67	[4]	139	[5]
Accretion		141		137
AROs, Ending balance		$ 3,923		$ 3,820
[1]	Includes $179 million and $198 million reported in other current liabilities at December 31, 2020 and 2021, respectively
[2]	Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, estimated cash flow projections associated with the recovery of spent nuclear fuel costs for its AROs associated with the decommissioning of Kewaunee and estimated cash flow projections associated with certain gas distribution pipelines.  These revisions in 2021 resulted in a charge of $44 million ($35 million after-tax) within other operations and maintenance expense in the Consolidated Statements of Income as well as a $173 million decrease to property, plant and equipment, net.
[3]	Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities, asbestos abatement costs associated with certain utility facilities and from the completion of a nuclear decommissioning cost study related to Summer.
[4]	Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities.
[5]	Reflects revisions to future ash pond and landfill closure costs at certain utility generation facilities and asbestos abatement costs associated with certain utility facilities.

Asset Retirement Obligations _2

Asset Retirement Obligations (Changes to AROs) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	$ 31	$ 67
Property, plant and equipment, net, decrease	173
Other Current Liabilities
Asset Retirement Obligations [Line Items]
Asset retirement obligations	198	179
Other Operations and Maintenance
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	44
Asset retirement obligation, liabilities incurred after tax	35
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
Asset retirement obligations	191	166
Asset retirement obligation, liabilities incurred	$ 26	$ 48
Virginia Electric and Power Company | Other Operations and Maintenance
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred			$ 113
ARO incurred, after tax			$ 84

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	$ 31	$ 67
Nuclear decommissioning trust funds	7,950	6,900
Dominion Energy
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	2,000	1,900
D Virginia Electric And Power Company | Future Decommissioning Of Nuclear Facilities
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	900	900
D Virginia Electric And Power Company | D Cost Of Landfills And Beneficial Reuse
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	2,900	2,800
Virginia Electric and Power Company
Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities incurred	26	48
Nuclear decommissioning trust funds	$ 3,734	$ 3,197

Leases (Lease Assets and Liabil

Leases (Lease Assets and Liabilities Recorded in Consolidated Balance Sheets) (Detail) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020		Jan. 01, 2019
Lessee Lease Disclosure [Line Items]
Operating lease assets		$ 506	[1]	$ 564	[1]	$ 504
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		us-gaap:PrepaidExpenseAndOtherAssetsNoncurrent		us-gaap:PrepaidExpenseAndOtherAssetsNoncurrent
Finance lease assets	[2]	$ 144		$ 148
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		Property, plant and equipment		Property, plant and equipment
Total lease assets		$ 650		$ 712
Operating lease liabilities	[3]	$ 44		$ 54
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Other		Other
Finance lease liabilities	[4]	$ 36		$ 32
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Securities due within one year		Securities due within one year
Total lease liabilities - current		$ 80		$ 86
Operating lease liabilities	[5]	$ 464		$ 516
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Deferred Credits And Other Liabilities		Deferred Credits And Other Liabilities
Finance lease liabilities	[6]	$ 112		$ 108
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other		Other
Total lease liabilities - noncurrent		$ 576		$ 624
Total lease liabilities		656		710
Virginia Electric and Power Company
Lessee Lease Disclosure [Line Items]
Operating lease assets		$ 256	[1]	$ 185	[1]	$ 209
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		us-gaap:PrepaidExpenseAndOtherAssetsNoncurrent		us-gaap:PrepaidExpenseAndOtherAssetsNoncurrent
Finance lease assets	[2]	$ 71		$ 45
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]		Property, plant and equipment		Property, plant and equipment
Total lease assets		$ 327		$ 230
Operating lease liabilities	[3]	$ 25		$ 28
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Other		Other
Finance lease liabilities	[4]	$ 13		$ 8
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Securities due within one year		Securities due within one year
Total lease liabilities - current		$ 38		$ 36
Operating lease liabilities	[5]	$ 227		$ 155
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Deferred Credits And Other Liabilities		Deferred Credits And Other Liabilities
Finance lease liabilities	[6]	$ 57		$ 36
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other		Other
Total lease liabilities - noncurrent		$ 284		$ 191
Total lease liabilities		$ 322		$ 227
[1]	Included in other deferred charges and other assets in the Companies’ Consolidated Balance Sheets.
[2]	Included in property, plant and equipment in the Companies’ Consolidated Balance Sheets, net of $81 million and $18 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2021 and net of $50 million and $9 million of accumulated amortization at Dominion Energy and Virginia Power, respectively, at December 31, 2020.
[3]	Included in other current liabilities in the Companies’ Consolidated Balance Sheets.
[4]	Included in securities due within one year in the Companies’ Consolidated Balance Sheets.
[5]	Included in other deferred credits and other liabilities in the Companies’ Consolidated Balance Sheets.
[6]	Included in other long-term debt in the Companies’ Consolidated Balance Sheets.

Leases (Lease Assets and Liab_2

Leases (Lease Assets and Liabilities Recorded in Consolidated Balance Sheets) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Lessee Lease Disclosure [Line Items]
Finance lease assets, accumulated amortization	$ 81	$ 50
Virginia Electric and Power Company
Lessee Lease Disclosure [Line Items]
Finance lease assets, accumulated amortization	$ 18	$ 9

Leases (Narrative) (Detail)

Leases (Narrative) (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2020	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Leases Disclosure [Line Items]
Property, plant and equipment	$ 57,848		$ 59,774	$ 57,848
Accumulated depreciation, depletion and amortization	$ 25,111		26,729	25,111
Agreement with Lessor to Complete Construction and Lease Jones Act Compliant Offshore Wind Installation Vessel
Leases Disclosure [Line Items]
Requested cash draws from lessor to fund project costs			293
Required percentage payment for specific full recourse events	100.00%
Lease maturity term	2027-11
Lessor | Agreement with Lessor to Complete Construction and Lease Jones Act Compliant Offshore Wind Installation Vessel
Leases Disclosure [Line Items]
Amount of financing commitments to fund estimated project costs	$ 550			550
Lessor | New Corporate Office | Agreement with Lessor to Construct and Lease Corporate Office Property
Leases Disclosure [Line Items]
Amount of financing commitments to fund estimated project costs					$ 465
Leasing arrangement, charge			62
Leasing arrangement, charge after tax			46
Lease effective termination date		2021-04
Power Purchase Arrangement [Member]
Leases Disclosure [Line Items]
Property, plant and equipment	2,200		1,200	2,200
Accumulated depreciation, depletion and amortization	$ 68		106	68
Rental revenue			168	175	174
Depreciation expense			$ 110	$ 102	$ 94

Leases (Summary of Total Lease

Leases (Summary of Total Lease Cost) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finance lease cost:
Finance lease cost, Amortization	$ 40	$ 33	$ 20
Finance lease cost, Interest	(3)		4
Operating lease cost	66	68	79
Short-term lease cost	32	20	26
Variable lease cost	5	8	5
Total lease cost	140	129	134
Virginia Electric and Power Company
Finance lease cost:
Finance lease cost, Amortization	12	7	3
Finance lease cost, Interest	1	1
Operating lease cost	30	36	41
Short-term lease cost	19	12	13
Variable lease cost	1	4	2
Total lease cost	$ 63	$ 60	$ 59

Leases (Cash Paid for Amounts I

Leases (Cash Paid for Amounts Included in Measurement of Lease Liabilities) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee Lease Disclosure [Line Items]
Operating cash flows for finance leases	$ (3)		$ 4
Operating cash flows for operating leases	103	$ 96	111
Financing cash flows for finance leases	40	33	20
Virginia Electric and Power Company
Lessee Lease Disclosure [Line Items]
Operating cash flows for finance leases	1	1
Operating cash flows for operating leases	53	52	56
Financing cash flows for finance leases	$ 12	$ 7	$ 3

Leases (Weighted Average Remain

Leases (Weighted Average Remaining Lease Term and Weighted Discounted Rate for Finance and Operating Leases) (Detail)	Dec. 31, 2021	Dec. 31, 2020
Lessee Lease Disclosure [Line Items]
Weighted average remaining lease term - finance leases	5 years	5 years
Weighted average remaining lease term - operating leases	27 years	26 years
Weighted average discount rate - finance leases	2.77%	3.17%
Weighted average discount rate - operating leases	3.96%	4.07%
Virginia Electric and Power Company
Lessee Lease Disclosure [Line Items]
Weighted average remaining lease term - finance leases	6 years	6 years
Weighted average remaining lease term - operating leases	25 years	21 years
Weighted average discount rate - finance leases	2.27%	2.51%
Weighted average discount rate - operating leases	4.00%	4.26%

Leases (Scheduled Maturities of

Leases (Scheduled Maturities of Lease Liabilities) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Lessee Lease Disclosure [Line Items]
Maturity of Lease Liabilities, Operating, 2022	$ 50
Maturity of Lease Liabilities, Operating, 2023	41
Maturity of Lease Liabilities, Operating, 2024	33
Maturity of Lease Liabilities, Operating, 2025	27
Maturity of Lease Liabilities, Operating, 2026	24
Maturity of Lease Liabilities, Operating, After 2026	577
Maturity of Lease Liabilities, Operating, Total undiscounted lease payments	752
Present value adjustment, Operating	(244)
Present value of lease liabilities, Operating	508
Maturity of Lease Liabilities, Finance, 2022	32
Maturity of Lease Liabilities, Finance, 2023	39
Maturity of Lease Liabilities, Finance, 2024	33
Maturity of Lease Liabilities, Finance, 2025	18
Maturity of Lease Liabilities, Finance, 2026	15
Maturity of Lease Liabilities, Finance, After 2026	22
Maturity of Lease Liabilities, Finance, Total undiscounted lease payments	159
Present value adjustment, Finance	(11)
Present value of lease liabilities, Finance	148
Virginia Electric and Power Company
Lessee Lease Disclosure [Line Items]
Maturity of Lease Liabilities, Operating, 2022	27
Maturity of Lease Liabilities, Operating, 2023	21
Maturity of Lease Liabilities, Operating, 2024	17
Maturity of Lease Liabilities, Operating, 2025	13
Maturity of Lease Liabilities, Operating, 2026	10
Maturity of Lease Liabilities, Operating, After 2026	240
Maturity of Lease Liabilities, Operating, Total undiscounted lease payments	328
Present value adjustment, Operating	(76)
Present value of lease liabilities, Operating	252
Maturity of Lease Liabilities, Finance, 2022	8
Maturity of Lease Liabilities, Finance, 2023	14
Maturity of Lease Liabilities, Finance, 2024	14
Maturity of Lease Liabilities, Finance, 2025	13
Maturity of Lease Liabilities, Finance, 2026	10
Maturity of Lease Liabilities, Finance, After 2026	17
Maturity of Lease Liabilities, Finance, Total undiscounted lease payments	76
Present value adjustment, Finance	(6)
Present value of lease liabilities, Finance	$ 70

Variable Interest Entities - (N

Variable Interest Entities - (Narrative) (Detail) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	May 31, 2019USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)GeneratorMW
Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Long-term debt			$ 13,453	$ 13,207
Payables to affiliates			121	266
Variable Interest Entity, Primary Beneficiary | SBL Holdco
Variable Interest Entity [Line Items]
Securities due within one year			32
Long-term debt			$ 239
Variable Interest Entity, Primary Beneficiary | Partnership Interest | Merchant Solar Projects
Variable Interest Entity [Line Items]
Initial membership interest percentage			67.00%
Variable Interest Entity Not Primary Beneficiary | Distribution | Atlantic Coast Pipeline | Pipelines | Jointly Owned Natural Gas Pipeline
Variable Interest Entity [Line Items]
Initial membership interest percentage			53.00%
Variable Interest Entity Not Primary Beneficiary | Virginia Electric and Power Company | DES
Variable Interest Entity [Line Items]
Shared Services Purchased			$ 380	349	$ 387
Payables to affiliates			$ 20	$ 175
Variable Interest Entity Not Primary Beneficiary | Partnership Interest | Cove Point
Variable Interest Entity [Line Items]
Initial membership interest percentage			50.00%
Variable Interest Entity V I E And Potential V I E Information Unavailability | Virginia Electric and Power Company
Variable Interest Entity [Line Items]
Long term capacity contract non utility generators (generators) | Generator					1
Aggregate generation capacity from long-term power and capacity contracts (MW) | MW					218
Payment for contract termination	$ 135	$ 135
Payment for contract termination after tax		$ 100
Payment for electric capacity					$ 13
Payment for electric energy					$ 1

Short-Term Debt and Credit Agre

Short-Term Debt and Credit Agreements (Narrative) (Detail) - USD ($)		1 Months Ended		12 Months Ended
		Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2021	Jul. 31, 2021	Jun. 30, 2021	Dec. 31, 2020	Oct. 31, 2020	Apr. 30, 2020	Dec. 31, 2019	Nov. 30, 2017
Debt Instrument [Line Items]
Facility Limit	[1]			$ 6,000,000,000			$ 6,000,000,000
Short-term debt				2,314,000,000			895,000,000
Letters of credit outstanding, amount	[1]			131,000,000			100,000,000
Floating Rate Demand Notes
Debt Instrument [Line Items]
Short-term debt				431,000,000			268,000,000
Floating Rate Demand Notes | Shelf Registration for Sale of Demand Notes
Debt Instrument [Line Items]
Facility Limit											$ 3,000,000,000
Debt instrument, maximum principal outstanding amount								$ 1,000,000,000
Dominion Energy South Carolina Inc
Debt Instrument [Line Items]
Facility Limit				500,000,000
Short-term indebtedness outstanding		$ 2,200,000,000
Debt, maturity month and year		2023-03
Questar Gas
Debt Instrument [Line Items]
Facility Limit				250,000,000
GENCO
Debt Instrument [Line Items]
Short-term indebtedness outstanding		$ 200,000,000
Debt, maturity month and year		2023-03
SBL Holdco
Debt Instrument [Line Items]
Facility Limit				30,000,000
Short-term debt							0
Dominion Solar Projects III, Inc
Debt Instrument [Line Items]
Facility Limit				25,000,000
Short-term debt							0
Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit						$ 6,000,000,000
Letter of Credit
Debt Instrument [Line Items]
Facility Limit				$ 2,000,000,000
Letter of Credit | Credit Facility, Maturing in June 2022
Debt Instrument [Line Items]
Facility Limit									$ 30,000,000
Credit facility, maturity date				Jun. 30, 2022
Credit facility, amount borrowed							29,000,000			$ 30,000,000
364-Day Revolving Credit Facility
Debt Instrument [Line Items]
Facility Limit			$ 900,000,000
Short-term debt							$ 225,000,000
Debt Instrument Term			364 days
Term Loan Credit Agreement
Debt Instrument [Line Items]
Facility Limit					$ 1,300,000,000
Credit Facilities Maturing in December 2021 with 1 Year Automatic Renewals Through 2024 | DECP Holdings
Debt Instrument [Line Items]
Facility Limit				$ 110,000,000
Automatic renewal period				1 year
Letters of credit outstanding, amount				$ 110,000,000
Letters of credit borrowed, amount				$ 0
[1]	This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility 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.

Short-Term Debt and Credit Ag_2

Short-Term Debt and Credit Agreements (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Detail) - USD ($)		Dec. 31, 2021	Dec. 31, 2020
Line of Credit Facility [Line Items]
Facility Limit	[1]	$ 6,000,000,000	$ 6,000,000,000
Outstanding Commercial Paper	[1],[2]	1,883,000,000	627,000,000
Outstanding Letters of Credit	[1]	131,000,000	100,000,000
Facility Capacity Available	[1]	3,986,000,000	5,273,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	[3]	6,000,000,000	6,000,000,000
Outstanding Commercial Paper	[3],[4]	745,000,000	45,000,000
Outstanding Letters of Credit	[3]	$ 40,000,000	$ 12,000,000
[1]	This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility to support bank borrowings and the issuance of commercial paper, as well as to support up to a combined $2.0 billion of letters of credit.
[2]	The weighted-average interest rates of the outstanding commercial paper supported by Dominion Energy’s credit facility was 0.31% and 0.29% at December 31, 2021 and 2020, respectively.
[3]	The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Questar Gas and DESC. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At December 31, 2021, the sub-limit for Virginia Power was $1.75 billion. If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion Energy. This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028. The credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit.
[4]	The weighted-average interest rates of the outstanding commercial paper supported by the credit facility was 0.26% and 0.30% at December 31, 2021 and 2020, respectively.

Short-Term Debt and Credit Ag_3

Short-Term Debt and Credit Agreements (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Parenthetical) (Detail) - USD ($)		Dec. 31, 2021	Dec. 31, 2020
Line of Credit Facility [Line Items]
Weighted-average percentage interest rates		0.31%	0.29%
Facility Limit	[1]	$ 6,000,000,000	$ 6,000,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Weighted-average percentage interest rates		0.26%	0.30%
Facility Limit	[2]	$ 6,000,000,000	$ 6,000,000,000
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
Line of Credit | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit		$ 1,750,000,000
[1]	This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028, and can be used by the borrowers under the credit facility 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, Questar Gas and DESC. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At December 31, 2021, the sub-limit for Virginia Power was $1.75 billion. If Virginia Power has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion Energy. This credit facility matures in June 2026, with the potential to be extended by the borrowers to June 2028. The credit facility 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.

Long-Term Debt (Total Long Term

Long-Term Debt (Total Long Term Debt) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Weighted-average percentage interest rates		0.31%	0.29%
Total principal	[1]	$ 37,694	$ 35,496
Securities due within one year	[2]	(805)	(1,905)
Unamortized discount, premium and debt issuances costs, net		(315)	(293)
Derivative restructuring		738	773
Finance lease liabilities	[3]	112	108
Total long-term debt		37,426	33,957
Supplemental 364-Day credit facility, variable rate, due 2021			225
Fair value hedge valuation	[4]	$ 2	3
Long term debt due within one year
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[2],[5]	2.79%
Supplemental 364-Day credit facility, variable rate, due 2021
Debt Instrument [Line Items]
Supplemental 364-Day credit facility, variable rate, due 2021			225
4.82%, due 2042
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[6]	4.82%
Total principal	[6]	$ 314	331
Term loans, variable rates, due 2023 and 2024
Debt Instrument [Line Items]
Total principal	[7]		476
Senior Notes | Variable rates, due 2023
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	0.73%
Total principal		$ 1,000	1,000
Senior Notes | 1.45% to 7.0%, due 2021 to 2049
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[8]	3.78%
Total principal	[8]	$ 11,238	9,938
Tax-Exempt Financings | Variable Rate Due 2038
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[9]	0.14%
Total principal	[9]	$ 35	35
Tax-Exempt Financings | GENCO variable rate due 2038 [Member]
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[9]	0.14%
Total principal	[9]	$ 33	33
Tax-Exempt Financings | 3.625% and 4.00%, due 2028 and 2033
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[9]	3.90%
Total principal	[9]	$ 54	54
Tax-Exempt Financings | Other
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[9]	3.65%
Total principal	[9]	$ 1	1
Tax-Exempt Financings | Tax-Exempt Financing, 1.7% due 2033
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	1.70%
Total principal		$ 27	27
Junior Subordinated Debt | 8.4% due 2031
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	8.40%
Total principal		$ 10	10
Junior Subordinated Debt | 2.715% to 4.104%, Due 2021 and 2024
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	3.07%
Total principal		$ 700	1,950
Enhanced Junior Subordinated Notes | 5.25% and 5.75%, due 2054 and 2076
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[10]	5.75%
Total principal	[10]	$ 685	1,485
Questar Gas | 2.21% to 7.20%, due 2024 to 2051
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	3.85%
Total principal		$ 1,000	750
DECP Holdings | Term Loan, Variable Rate, Due 2024
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[11]	1.50%
Total principal	[11]	$ 2,500
East Ohio | 1.30% to 3.00%, due 2025 to 2050
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	2.25%
Total principal		$ 1,800	1,800
PSNC | 3.10% to 7.45%, due 2021 to 2051
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	4.34%
Total principal		$ 800	800
DESC | First mortgage bonds, 2.30% to 6.625%, due 2021 to 2065
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	5.09%
Total principal		$ 3,634	$ 3,267
Virginia Electric and Power Company
Debt Instrument [Line Items]
Weighted-average percentage interest rates		0.26%	0.30%
Total principal		$ 13,863	$ 13,314
Securities due within one year		(300)
Unamortized discount, premium and debt issuances costs, net		(110)	(107)
Derivative restructuring		446	444
Finance lease liabilities	[3]	57	36
Total long-term debt		$ 13,956	13,687
Virginia Electric and Power Company | Long term debt due within one year
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	3.45%
Virginia Electric and Power Company | Senior Notes | 2.30% to 8.875%, due 2022 to 2051
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5]	4.07%
Total principal		$ 13,238	12,689
Virginia Electric and Power Company | Tax-Exempt Financings | 0.45% to 1.90%, due 2032 to 2041
Debt Instrument [Line Items]
Weighted-average percentage interest rates	[5],[12]	1.14%
Total principal	[12]	$ 625	$ 625
[1]	Excludes amounts classified as held for sale at December 31, 2020. See Note 3.
[2]	At December 31, 2020, includes $22 million of estimated mandatory prepayments due within one year based on estimated cash flows in excess of debt service at SBL Holdco and Dominion Solar Projects III, Inc.
[3]	Included in other long-term debt in the Companies’ Consolidated Balance Sheets.
[4]	Represents the valuation of certain fair value hedges associated with Dominion Energy’s fixed rate debt.
[5]	Represents weighted-average coupon rates for debt outstanding as of December 31, 2021.
[6]	Represents debt associated with Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain solar facilities.
[7]	Represents debt associated with SBL Holdco and Dominion Solar Projects III, Inc. The debt was nonrecourse to Dominion Energy and was secured by SBL Holdco’s and Dominion Solar Projects III, Inc’s interest in certain solar facilities. In connection with the sales of certain non-wholly owned nonregulated solar facilities discussed in Note 10, the outstanding debt of SBL Holdco was assumed by Terra Nova Renewable Partners and Dominion Energy utilized proceeds from Clearway to repay the outstanding balance of the Dominion Solar Projects III, Inc. term loan.
[8]	Includes debt assumed by Dominion Energy from the merger of its former CNG subsidiary.
[9]	Industrial revenue bonds totaling $68 million are secured by letters of credit that expire, subject to renewal, in the fourth quarter of 2022.
[10]	In August 2021, Dominion Energy redeemed the remaining principal outstanding of $800 million of its July 2016 hybrids, which would have otherwise matured in 2076.
[11]	The term loan amortizes over a 17-year period and matures in December 2024 with the potential to be extended to December 2026. The debt is secured by DECP Holdings’ noncontrolling interest in Cove Point.
[12]	These financings relate to certain pollution control equipment at Virginia Power’s generating facilities.

Long-Term Debt (Total Long Te_2

Long-Term Debt (Total Long Term Debt) (Parenthetical) (Detail) - USD ($) $ in Millions		1 Months Ended
		Aug. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Jul. 31, 2016
Debt Instrument [Line Items]
Total principal	[1]		$ 37,694	$ 35,496
Sustainability Revolving Credit Agreement
Debt Instrument [Line Items]
Debt instrument, face amount			900
Sustainability Revolving Credit Agreement | June Twenty Twenty One
Debt Instrument [Line Items]
Debt, amount redeemed			250
Sustainability Revolving Credit Agreement | August Twenty Twenty One
Debt Instrument [Line Items]
Debt, amount redeemed			650
Junior Subordinated Debt
Debt Instrument [Line Items]
Interest Rate					5.25%
Debt instrument, face amount					$ 800
Term loans
Debt Instrument [Line Items]
Estimated mandatory prepayments due within one year				22
Virginia Electric and Power Company
Debt Instrument [Line Items]
Total principal			13,863	13,314
2.30% to 8.875%, due 2022 to 2051 | Virginia Electric and Power Company | Senior Notes
Debt Instrument [Line Items]
Total principal			$ 13,238	12,689
2.30% to 8.875%, due 2022 to 2051 | Minimum | Virginia Electric and Power Company | Senior Notes
Debt Instrument [Line Items]
Interest Rate			2.30%
2.30% to 8.875%, due 2022 to 2051 | Maximum | Virginia Electric and Power Company | Senior Notes
Debt Instrument [Line Items]
Interest Rate			8.875%
0.45% to 1.90%, due 2032 to 2041 | Virginia Electric and Power Company | Tax-Exempt Financings
Debt Instrument [Line Items]
Total principal	[2]		$ 625	625
0.45% to 1.90%, due 2032 to 2041 | Minimum | Virginia Electric and Power Company | Tax-Exempt Financings
Debt Instrument [Line Items]
Interest Rate			0.45%
0.45% to 1.90%, due 2032 to 2041 | Maximum | Virginia Electric and Power Company | Tax-Exempt Financings
Debt Instrument [Line Items]
Interest Rate			1.90%
1.45% to 7.0%, due 2021 to 2049 | Senior Notes
Debt Instrument [Line Items]
Total principal	[3]		$ 11,238	9,938
1.45% to 7.0%, due 2021 to 2049 | Minimum | Senior Notes
Debt Instrument [Line Items]
Interest Rate			1.45%
1.45% to 7.0%, due 2021 to 2049 | Maximum | Senior Notes
Debt Instrument [Line Items]
Interest Rate			7.00%
2.715% to 4.104%, Due 2021 and 2024 | Junior Subordinated Debt
Debt Instrument [Line Items]
Total principal			$ 700	1,950
2.715% to 4.104%, Due 2021 and 2024 | Minimum | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest Rate			2.715%
2.715% to 4.104%, Due 2021 and 2024 | Maximum | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest Rate			4.104%
8.4% due 2031 | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest Rate			8.40%
Total principal			$ 10	10
5.25% and 5.75%, due 2054 and 2076 | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Total principal	[4]		$ 685	1,485
5.25% and 5.75%, due 2054 and 2076 | Minimum | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Interest Rate			5.25%
5.25% and 5.75%, due 2054 and 2076 | Maximum | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Interest Rate			5.75%
2.21% to 7.20%, due 2024 to 2051 | Minimum | Questar Gas Company
Debt Instrument [Line Items]
Interest Rate			2.21%
2.21% to 7.20%, due 2024 to 2051 | Maximum | Questar Gas Company
Debt Instrument [Line Items]
Interest Rate			7.20%
1.30% to 3.00%, due 2025 to 2050 | Minimum | East Ohio
Debt Instrument [Line Items]
Interest Rate			1.30%
1.30% to 3.00%, due 2025 to 2050 | Maximum | East Ohio
Debt Instrument [Line Items]
Interest Rate			3.00%
3.10% to 7.45%, due 2021 to 2051 | Minimum | PSNC
Debt Instrument [Line Items]
Interest Rate			3.10%
3.10% to 7.45%, due 2021 to 2051 | Maximum | PSNC
Debt Instrument [Line Items]
Interest Rate			7.45%
First mortgage bonds, 2.30% to 6.625%, due 2021 to 2065 | Minimum | DESC
Debt Instrument [Line Items]
Interest Rate			2.30%
First mortgage bonds, 2.30% to 6.625%, due 2021 to 2065 | Maximum | DESC
Debt Instrument [Line Items]
Interest Rate			6.625%
3.625% and 4.00%, due 2028 and 2033 | Tax-Exempt Financings
Debt Instrument [Line Items]
Total principal	[5]		$ 54	54
3.625% and 4.00%, due 2028 and 2033 | Minimum | Tax-Exempt Financings
Debt Instrument [Line Items]
Interest Rate			3.625%
3.625% and 4.00%, due 2028 and 2033 | Maximum | Tax-Exempt Financings
Debt Instrument [Line Items]
Interest Rate			4.00%
4.82%, due 2042
Debt Instrument [Line Items]
Interest Rate			4.82%
Total principal	[6]		$ 314	331
Tax-Exempt Financing, 1.7% due 2033
Debt Instrument [Line Items]
Interest Rate			1.70%
Tax-Exempt Financing, 1.7% due 2033 | Tax-Exempt Financings
Debt Instrument [Line Items]
Total principal			$ 27	$ 27
July2016 Hybrids | Junior Subordinated Debt
Debt Instrument [Line Items]
Debt instrument, face amount		$ 800
Debt instrument maturity year		2076
Industrial Revenue Bonds
Debt Instrument [Line Items]
Total principal			$ 68
[1]	Excludes amounts classified as held for sale at December 31, 2020. See Note 3.
[2]	These financings relate to certain pollution control equipment at Virginia Power’s generating facilities.
[3]	Includes debt assumed by Dominion Energy from the merger of its former CNG subsidiary.
[4]	In August 2021, Dominion Energy redeemed the remaining principal outstanding of $800 million of its July 2016 hybrids, which would have otherwise matured in 2076.
[5]	Industrial revenue bonds totaling $68 million are secured by letters of credit that expire, subject to renewal, in the fourth quarter of 2022.
[6]	Represents debt associated with Eagle Solar. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain solar facilities.

Long-Term Debt (Based on Stated

Long-Term Debt (Based on Stated Maturity Dates Rather than Early Redemption Dates that Could be Elected by Instrument Holders) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Debt Instrument [Line Items]
2022	$ 807
2023	2,851
2024	3,636
2025	2,019
2026	2,277
Thereafter	26,104
Total	$ 37,694
Weighted- average coupon, 2022	2.79%
Weighted- average coupon, 2023	1.89%
Weighted- average coupon, 2024	2.20%
Weighted- average coupon, 2025	3.01%
Weighted- average coupon, 2026	2.82%
Weighted- average coupon, Thereafter	4.26%
Unsecured senior notes
Debt Instrument [Line Items]
2022	$ 650
2023	2,700
2024	690
2025	2,000
2026	2,257
Thereafter	20,779
Total	29,076
Tax-exempt financings
Debt Instrument [Line Items]
Thereafter	775
Total	775
Term loans
Debt Instrument [Line Items]
2022	151
2023	134
2024	2,215
Total	2,500
First mortgage bonds
Debt Instrument [Line Items]
Thereafter	3,634
Total	3,634
Secured senior notes
Debt Instrument [Line Items]
2022	6
2023	17
2024	31
2025	19
2026	20
Thereafter	221
Total	314
Unsecured junior subordinated notes payable to affiliated trusts
Debt Instrument [Line Items]
Thereafter	10
Total	10
Unsecured junior subordinated notes
Debt Instrument [Line Items]
2024	700
Total	700
Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Thereafter	685
Total	685
Virginia Electric and Power Company
Debt Instrument [Line Items]
2022	300
2023	700
2024	350
2025	350
2026	1,150
Thereafter	11,013
Total	$ 13,863
Weighted- average coupon, 2022	3.45%
Weighted- average coupon, 2023	2.75%
Weighted- average coupon, 2024	3.45%
Weighted- average coupon, 2025	3.10%
Weighted- average coupon, 2026	3.08%
Weighted- average coupon, Thereafter	4.16%
Virginia Electric and Power Company | Unsecured senior notes
Debt Instrument [Line Items]
2022	$ 300
2023	700
2024	350
2025	350
2026	1,150
Thereafter	10,388
Total	13,238
Virginia Electric and Power Company | Tax-exempt financings
Debt Instrument [Line Items]
Thereafter	625
Total	$ 625

Long-Term Debt (Narrative) (Det

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

Oct. 01, 2024

Aug. 31, 2021

Aug. 31, 2020

Jun. 30, 2020

Feb. 29, 2020

Sep. 30, 2006

Jun. 30, 2006

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Jan. 31, 2022

Jul. 31, 2016

Oct. 31, 2014

Debt Instrument [Line Items]

Debt, amount redeemed

$ 39,000,000

Repayments of Long-term Debt

$ 3,750,000,000

$ 2,879,000,000

$ 9,116,000,000

Period of deferral

10 days

Other long-term debt

$ 850,000,000

881,000,000

Interest Rate Swap

Debt Instrument [Line Items]

Derivative notional value

$ 2,000,000,000

Derivative maturity month and year

2024-12

Other long-term debt

$ 326,000,000

Derivative imputed interest rate

1.19%

Interest Rate Swap | Virginia Power

Debt Instrument [Line Items]

Derivative notional value

$ 900,000,000

Derivative maturity month and year

2023-12

Other long-term debt

$ 443,000,000

Derivative imputed interest rate

0.34%

Junior Subordinated Debt

Debt Instrument [Line Items]

Interest rate percentage

5.25%

Debt instrument, face amount

$ 800,000,000

June 2006 Hybrids

Debt Instrument [Line Items]

Debt, amount redeemed

12,000,000

Junior subordinated notes

$ 300,000,000

Repayments of Long-term Debt

$ 111,000,000

June 2006 Hybrids | LIBOR

Debt Instrument [Line Items]

Spread on variable percentage rate

2.825%

September 2006 Hybrids

Debt Instrument [Line Items]

Junior subordinated notes

$ 500,000,000

Debt instrument, face amount

$ 13,000,000

Repayments of Long-term Debt

$ 286,000,000

September 2006 Hybrids | LIBOR

Debt Instrument [Line Items]

Spread on variable percentage rate

2.30%

June 2006 and September 2006 Hybrids | Interest and Related Charges

Debt Instrument [Line Items]

Expenses related to early redemption of hybrids

$ 10,000,000

October 2014 Hybrids | Junior Subordinated Debt

Debt Instrument [Line Items]

Interest rate percentage

5.75%

Debt instrument, face amount

$ 685,000,000

Senior Notes Due in 2032 | Subsequent Event

Debt Instrument [Line Items]

Debt, amount redeemed

$ 600,000,000

Interest rate percentage

2.40%

Senior Notes Due in 2051 | Subsequent Event

Debt Instrument [Line Items]

Debt, amount redeemed

$ 400,000,000

Interest rate percentage

2.95%

July2016 Hybrids | Junior Subordinated Debt

Debt Instrument [Line Items]

Debt, amount redeemed

800,000,000

Debt instrument, face amount

800,000,000

Expenses related to early redemption of hybrids

$ 23,000,000

Debt instrument maturity year

2076

July2016 Hybrids | October 2014 Hybrids | Scenario, Forecast

Debt Instrument [Line Items]

Spread on variable percentage rate

3.057%

Preferred Stock (Narrative) (De

Preferred Stock (Narrative) (Detail) - USD ($)	1 Months Ended			12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 15, 2027	Dec. 15, 2024	Jun. 30, 2019	Jun. 14, 2019
Class of Stock [Line Items]
Preferred stock shares authorized		20,000,000		20,000,000
Stock issued during period for acquisition, value						$ 6,818,000,000
Total Preferred Stock		$ 1,783,000,000		$ 1,783,000,000	$ 2,387,000,000
Dividend stock				68,000,000	$ 65,000,000	17,000,000
Common Stock
Class of Stock [Line Items]
Stock issued during period for acquisition, value						6,818,000,000
Defined Benefit Pension plans						$ 499,000,000
2019 Series A Corporate Units
Class of Stock [Line Items]
Principal amount corporate units										$ 1,600,000,000
Percentage of interest in undivided beneficial ownership									10.00%
2019 Series A Corporate Units | Forecast
Class of Stock [Line Items]
Stock issued during period for acquisition, value	$ 1,600,000,000
2019 Series A Corporate Units | Forecast | Maximum
Class of Stock [Line Items]
Shares to be issued under purchase contracts	21,800,000
2019 Series A Corporate Units | Common Stock
Class of Stock [Line Items]
Purchase price to be paid under stock purchase contracts										$ 100
Series A Preferred Stock
Class of Stock [Line Items]
Reclassifications of permanent to mezzanine equity				$ 1,600,000,000
Conversion of stock, description				Series A Preferred Stock be settled, at Dominion Energy’s election, either entirely in cash or in cash up to the first $1,000 per share and in shares of Dominion Energy common stock, cash or any combination thereof for any amounts in excess of $1,000 per share.
Series B Preferred Stock
Class of Stock [Line Items]
Preferred stock, redemption price per share			$ 1,020			$ 1,020
Series B Preferred Stock | Forecast
Class of Stock [Line Items]
Preferred stock, redemption price per share								$ 1,000
Series C Preferred Stock
Class of Stock [Line Items]
Preferred stock, redemption price per share		$ 1,020		$ 1,020
Series C Preferred Stock | Forecast
Class of Stock [Line Items]
Preferred stock, redemption price per share							$ 1,000
Dominion Energy
Class of Stock [Line Items]
Dividend rate percentage		3.195%	2.993%
Dominion Energy | Preferred Class A
Class of Stock [Line Items]
Preferred stock shares issued		3,400,000		3,400,000	2,400,000
Preferred stock shares outstanding		3,400,000		3,400,000	2,400,000
Dominion Energy | Series A Preferred Stock
Class of Stock [Line Items]
Preferred stock shares issued		1,600,000		1,600,000	1,600,000
Preferred stock shares outstanding		1,600,000		1,600,000	1,600,000
Dominion Energy | Series B Preferred Stock
Class of Stock [Line Items]
Preferred stock shares issued		800,000	800,000	800,000	800,000	800,000
Preferred stock shares outstanding		800,000		800,000	800,000
Total Preferred Stock			$ 791,000,000			$ 791,000,000
Issuance of costs			9,000,000
Preferred stock liquidation value			$ 1,000			$ 1,000
Dividend rate percentage			4.65%
Dividend stock				$ 37,000,000	$ 37,000,000
Dividends per share				$ 46.50	$ 46.50
Dominion Energy | Series C Preferred Stock
Class of Stock [Line Items]
Preferred stock shares issued		1,000,000		1,000,000
Preferred stock shares outstanding		1,000,000		1,000,000
Issuance of costs		$ 8,000,000
Preferred stock liquidation value		$ 1,000		$ 1,000
Dividend rate percentage		4.35%
Dividend stock				$ 3,000,000
Dividends per share				$ 2.6583
Preferred stock shares issued to public		750,000
Preferred stock value issued to public		$ 742,000,000
Issuance of shares to qualified benefit pension plan		250,000
Defined Benefit Pension plans		$ 250,000,000
DESC
Class of Stock [Line Items]
Preferred stock shares authorized		20,000,000		20,000,000
SCANA
Class of Stock [Line Items]
Preferred Stock Held By SCANA		1,000		1,000	1,000
Virginia Electric and Power Company
Class of Stock [Line Items]
Preferred stock shares authorized		10,000,000		10,000,000
Preferred stock shares issued		0		0	0
Preferred stock shares outstanding		0		0	0
Liquidation preference		$ 100		$ 100

Preferred Stock (Schedule of Eq

Preferred Stock (Schedule of Equity Units) (Detail) - USD ($) shares in Millions, $ in Millions		Jun. 14, 2019	Aug. 31, 2021	Jul. 31, 2021	Sep. 30, 2020	Aug. 31, 2019	Dec. 31, 2021	Dec. 31, 2019	Dec. 31, 2020
Capital Unit [Line Items]
Units Issued			0.6	1.4	4.1	18.5		6.1
Total Preferred Stock							$ 1,783		$ 2,387
Stock Purchase Contract Liability							$ 44		$ 129
Preferred Stock
Capital Unit [Line Items]
Units Issued							1	2
Preferred Stock | 2019 Series A Corporate Units
Capital Unit [Line Items]
Units Issued		16
Total Net Proceeds	[1]	$ 1,582
Total Preferred Stock	[2]	$ 1,610
Cumulative Dividend Rate		1.75%
Stock Purchase Contract Annual Rate		5.50%
Stock Purchase Contract Liability	[3]	$ 250
Stock Purchase Contract Settlement Date		Jun. 1, 2022
[1]	Issuance costs of $28 million were recorded as a reduction to preferred stock ($14 million) and common stock ($14 million).
[2]	Dominion Energy recorded dividends of $28 million ($17.50 per share), $28 million ($17.50 per share) and $15 million ($9.479 per share) for the years ended December 31, 2021, 2020 and 2019, respectively.
[3]	Payments of $85 million, $83 million and $38 million were made in 2021, 2020 and 2019, respectively. The stock purchase contract liability was $44 million and $129 million at December 31, 2021 and 2020, respectively.

Preferred Stock (Schedule of _2

Preferred Stock (Schedule of Equity Units) (Parenthetical) (Detail) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Capital Unit [Line Items]
Issuance costs			$ 28
Corporate units stock purchase contract liability payments	$ 85	$ 83	38
Stock Purchase Contract Liability	44	129
Preferred Stock
Capital Unit [Line Items]
Issuance costs			14
Recorded dividend	$ 28	$ 28	$ 15
Dividends per share	$ 17.50	$ 17.50	$ 9.479
Common Stock
Capital Unit [Line Items]
Issuance costs			$ 14

Equity (Narrative) (Detail)

Equity (Narrative) (Detail)	1 Months Ended													3 Months Ended					12 Months Ended
	Dec. 31, 2021USD ($)shares	Nov. 30, 2021$ / sharesshares	Aug. 31, 2021USD ($)shares	Jul. 31, 2021USD ($)shares	Dec. 31, 2020USD ($)shares	Nov. 30, 2020USD ($)shares	Sep. 30, 2020USD ($)agreementshares	Aug. 31, 2020USD ($)	Mar. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)	Oct. 31, 2019	Aug. 31, 2019USD ($)shares	Jan. 31, 2019USD ($)shares	Dec. 31, 2020USD ($)shares	Sep. 30, 2020USD ($)shares	Dec. 31, 2019USD ($)shares	Mar. 31, 2019USD ($)shares	Dec. 31, 2018USD ($)shares	Dec. 31, 2021USD ($)shares	Dec. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)shares	Jul. 31, 2020USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Issuance of common stock												$ 1,400,000,000							$ 192,000,000	$ 159,000,000	$ 2,515,000,000
Issuance of common stock (in shares) | shares			600,000	1,400,000			4,100,000					18,500,000									6,100,000
Acquisition of SCANA																					$ 6,818,000,000
Amount of income taxes recognized in equity primarily attributable to establishing additional regulatory liabilities																					(40,000,000)
Issuance of common stock value			$ 45,000,000	$ 104,000,000															1,332,000,000	481,000,000	5,401,000,000
Fees and commissions paid																					28,000,000
Stock repurchased, shares | shares							4,100,000
Stock repurchased, value							$ 323,000,000													3,080,000,000
Number of prepaid accelerated share repurchase agreements | agreement							2
Accelerated share repurchase, payments					$ 400,000,000		$ 1,500,000,000							$ 400,000,000	$ 1,500,000,000					$ 400,000,000
Accelerated share repurchase, cash paid for number of shares exchange | shares					5,000,000		17,200,000							5,000,000	17,200,000					5,000,000
Decrease in common stock					$ 400,000,000	$ 1,500,000,000
Common stock worth based on closing Price					$ 400,000,000		$ 1,500,000,000							$ 400,000,000	$ 1,500,000,000					$ 400,000,000
Accelerated share repurchase, additional shares delivered under terms of the agreement | shares					300,000	1,400,000								300,000						300,000
Compensation cost related to stock-based compensation																			42,000,000	$ 64,000,000	46,000,000
Tax benefit from stock awards and stock options exercised																			$ 9,000,000	16,000,000	11,000,000
Vesting period																			3 years
Cash Based Performance Grant | Officer
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Cash-based performance grants minimum percentage																			0.00%
Cash-based performance grants maximum percentage																			200.00%
February2019 Cash Based Performance Grant | Officer | Grant Date Two
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Targeted amount of the grant	$ 5,700,000																		$ 5,700,000
February 2020 Cash Based Performance Grant | Officer | Grant Date Three
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Targeted amount of the grant	10,000,000																		10,000,000
Liability accrued for award	6,000,000																		6,000,000
February 2021 Cash Based Performance Grant | Officer | Grant Date Three
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Targeted amount of the grant	13,000,000																		13,000,000
Liability accrued for award	$ 4,000,000																		$ 4,000,000
Stock Based Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares were available for future grants | shares	19,000,000																		19,000,000
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation cost related to nonvested awards	$ 55,000,000																		$ 55,000,000
Fair value of restricted stock awards that vested																			$ 37,000,000	$ 35,000,000	$ 23,000,000
Cove Point
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Ownership interest percentage of limited partner interests						100.00%				25.00%	25.00%
Cash consideration from sale of noncontrolling interest										$ 2,100,000,000
Cove Point | GT&S Transaction
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Controlling interest sold						25.00%
Ownership percentage						50.00%
Reversal of noncontrolling interest held by noncontrolling owners						$ 1,400,000,000
S B L Holdco L L C | Nonregulated Solar Projects
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Controlling interest sold	67.00%
Four Brothers And Three Cedars
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Controlling interest sold	50.00%
Maximum | Stock Based Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Maximum term of stock based awards																			8 years
Weighted Average | Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected weighted-average period recognized for the unrecognized compensation cost																			2 years
Common Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Issuance of common stock (in shares) | shares																			4,000,000	7,000,000	39,000,000
Acquisition of SCANA (in shares) | shares																					96,000,000
Acquisition of SCANA																					$ 6,818,000,000
Amount of income taxes recognized in equity primarily attributable to establishing additional regulatory liabilities																					1,181,000,000
Defined Benefit Pension plans																					499,000,000
Issuance of common stock value																			$ 340,000,000	$ 481,000,000	3,014,000,000
Fees and commissions paid																					$ 14,000,000
Stock repurchased, shares | shares																			0	38,900,000	0
Stock repurchased, value						$ 1,000,000,000														$ 3,080,000,000
Stock repurchase program, authorized amount																						$ 3,000,000,000
Common Stock | Open Market Agreement
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock repurchased, shares | shares														3,700,000	7,200,000
Stock repurchased, value														$ 295,000,000	$ 562,000,000
Dominion Energy Midstream Partners, LP
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Acquisition of SCANA (in shares) | shares													22,500,000
Acquisition of SCANA													$ 1,600,000,000
Common units conversion ratio													0.2492
Gain or loss recognized in equity transaction													$ 0
Amount of income taxes recognized in equity primarily attributable to establishing additional regulatory liabilities													$ 40,000,000
Dominion Energy Direct
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Issuance of common stock																			$ 192,000,000	$ 159,000,000
Issuance of common stock (in shares) | shares																			2,600,000	2,100,000
SCANA
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Acquisition of SCANA (in shares) | shares													95,600,000								95,600,000
Acquisition of SCANA													$ 6,800,000,000								$ 6,800,000,000
Various Programs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Issuance of common stock																			$ 340,000,000	$ 481,000,000	$ 11,000,000,000
Issuance of common stock (in shares) | shares																			4,000,000	7,000,000	157,000,000
Sales Agency Agreements to Effect Sales Under At-the-market Program
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Issuance of common stock																$ 639,000,000	$ 154,000,000	$ 197,000,000
Issuance of common stock (in shares) | shares									0							7,800,000	2,100,000	2,700,000
Fees and commissions paid																$ 6,000,000	$ 2,000,000	$ 2,000,000
Sale of stock authorized amount									$ 500,000,000
Sales Agency Agreements to Effect Sales Under At-the-market Program | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sale of stock authorized amount								$ 1,000,000,000
Forward Sale Agreements
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Forward sale agreements, number of shares of common stock to be settled | shares		1,100,000
Initial forward price of share | $ / shares		$ 74.66

Equity (Schedule of Changes in

Equity (Schedule of Changes in AOCI Net of Tax and Reclassifications out of AOCI by Component) (Detail) - USD ($) $ in Millions		Nov. 30, 2020	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				$ 26,117
Operating Revenue				13,964	$ 14,172	$ 14,401
Interest and related charges				1,354	1,377	1,486
Income tax expense		$ 336	$ 173	425	83	209
Total, net of tax				(2,673)	(1,328)	(660)
Total other comprehensive income (loss)				259	76	(93)
Ending balance			27,308	27,308	26,117
Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				14,557	13,989	13,047
Operating Revenue	[1]			7,470	7,763	8,108
Interest and related charges	[1]			534	516	524
Total				(2,109)	(1,250)	(1,413)
Income tax expense				397	229	264
Total other comprehensive income (loss)				11	(23)	(17)
Ending balance			15,980	15,980	14,557	13,989
Commodity
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				(1)	16
Total, net of tax				1
Total other comprehensive income (loss)				1	(17)
Ending balance					(1)	16
Commodity | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Operating Revenue					(25)
Purchased gas				1	4
Income before income taxes					(2)
Total				1	(23)
Income tax expense					6
Total, net of tax					(17)
Interest rate
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				(418)	(426)
Other comprehensive income before reclassifications: gains (losses)				15	(231)
Total, net of tax				45
Total other comprehensive income (loss)				60	8
Ending balance			(358)	(358)	(418)	(426)
Interest rate | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Income before income taxes					236
Interest and related charges				60	83
Total				60	319
Income tax expense				(15)	(80)
Total, net of tax					239
Foreign currency exchange rate
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance					3
Other comprehensive income before reclassifications: gains (losses)					(8)
Total other comprehensive income (loss)					(3)
Ending balance						3
Foreign currency exchange rate | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Income before income taxes					6
Total					6
Income tax expense					(1)
Total, net of tax					5
Total Derivative-Hedging Activities
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[2]			(419)	(407)
Other comprehensive income before reclassifications: gains (losses)	[2]			15	(239)
Total, net of tax	[2]			46
Total other comprehensive income (loss)	[2]			61	(12)
Ending balance	[2]		(358)	(358)	(419)	(407)
Total Derivative-Hedging Activities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[3]			(60)	(34)
Other comprehensive income before reclassifications: gains (losses)	[3]			13	(28)
Total other comprehensive income (loss)	[3]			15	(26)
Ending balance	[3]		(45)	(45)	(60)	(34)
Total Derivative-Hedging Activities | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Operating Revenue	[2]				(25)
Purchased gas	[2]			1	4
Income before income taxes	[2]				240
Interest and related charges	[2]			60	83
Total	[2]			61	302
Income tax expense	[2]			(15)	(75)
Total, net of tax	[2]				227
Total Derivative-Hedging Activities | Amounts reclassified from AOCI | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Interest and related charges	[3]			3	2
Total	[3]			3	2
Income tax expense	[3]			(1)
Total, net of tax	[3]			2	2
Investment Securities
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[4]			62	37
Other comprehensive income before reclassifications: gains (losses)	[4]			(7)	43
Total, net of tax	[4]			(18)
Total other comprehensive income (loss)	[4]			(25)	25
Ending balance	[4]		37	37	62	37
Investment Securities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[5]			8	5
Other comprehensive income before reclassifications: gains (losses)	[5]			(2)	6
Total other comprehensive income (loss)	[5]			(4)	3
Ending balance	[5]		4	4	8	5
Investment Securities | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Other income	[4]			(23)	(24)
Total	[4]			(23)	(24)
Income tax expense	[4]			5	6
Total, net of tax	[4]				(18)
Investment Securities | Amounts reclassified from AOCI | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Other income	[5]			(3)	(4)
Total	[5]			(3)	(4)
Income tax expense	[5]			1	1
Total, net of tax	[5]			(2)	(3)
Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[6]			(1,359)	(1,421)
Other comprehensive income before reclassifications: gains (losses)	[6]			144	25
Total, net of tax	[6]			82
Total other comprehensive income (loss)	[6]			226	62
Ending balance	[6]		(1,133)	(1,133)	(1,359)	(1,421)
Pension and Other Postretirement Benefit Costs | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Other income	[6]			111	50
Total	[6]			111	50
Income tax expense	[6]			(29)	(13)
Total, net of tax	[6]				37
Equity Method Investees
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	[7]			(1)	(2)
Other comprehensive income before reclassifications: gains (losses)	[7]			(3)	1
Total other comprehensive income (loss)	[7]			(3)	1
Ending balance	[7]		(4)	(4)	(1)	(2)
AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				(1,717)	(1,793)
Other comprehensive income before reclassifications: gains (losses)				149	(170)
Total, net of tax				110
Total other comprehensive income (loss)				259	76	(93)
Ending balance			(1,458)	(1,458)	(1,717)	(1,793)
AOCI | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				(52)	(29)	(12)
Other comprehensive income before reclassifications: gains (losses)				11	(22)
Total other comprehensive income (loss)				11	(23)	(17)
Ending balance			(41)	(41)	(52)	(29)
AOCI | Amounts reclassified from AOCI
Accumulated Other Comprehensive Income Loss [Line Items]
Operating Revenue					(25)
Purchased gas				1	4
Income before income taxes					240
Interest and related charges				60	83
Other income				88	26
Total				149	328
Income tax expense				(39)	(82)
Total, net of tax					246
AOCI | Amounts reclassified from AOCI | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Interest and related charges				3	2
Other income				(3)	(4)
Total					(2)
Income tax expense					1
Total, net of tax					(1)
Interest Rate | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance				(60)	(34)
Other comprehensive income before reclassifications: gains (losses)				13	(28)
Total other comprehensive income (loss)				15	(26)
Ending balance			$ (45)	(45)	(60)	$ (34)
Interest Rate | Amounts reclassified from AOCI | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Interest and related charges				3	2
Total				3	2
Income tax expense				(1)
Total, net of tax				$ 2	$ 2
[1]	See Note 25 for amounts attributable to affiliates.
[2]	Net of $119 million
[3]	Net of $16 million and
[4]	Net of $(10) million and $(21) million tax at December 31, 2021 and 2020, respectively.
[5]	Net of $(2) million and $(3) million tax at December 31, 2021 and 2020, respectively.
[6]	Net of $396 million and $478 million tax at December 31, 2021 and 2020, respectively.
[7]	Net of $1 million and $— million tax at December 31, 2021 and 2020, respectively.

Equity (Schedule of Changes i_2

Equity (Schedule of Changes in AOCI Net of Tax and Reclassifications out of AOCI by Component) (Parenthetical) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Total Derivative-Hedging Activities
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	$ 119	$ 141
Total Derivative-Hedging Activities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	16	21
Investment Securities
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	(10)	(21)
Investment Securities | Virginia Electric and Power Company
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	(2)	(3)
Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	396	$ 478
Equity Method Investees
Accumulated Other Comprehensive Income Loss [Line Items]
Amount of tax	$ 1

Equity (Summary of Restricted S

Equity (Summary of Restricted Stock and Goal-Based Stock Activity) (Detail) - Restricted Stock - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested beginning (in shares)	1,410	1,402	1,208
Granted (in shares)	518	531	614
Vested (in shares)	(505)	(424)	(324)
Cancelled and forfeited (in shares)	(113)	(99)	(96)
Nonvested ending (in shares)	1,310	1,410	1,402
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Nonvested beginning, Weighted Average Grant Date Fair Value (in dollars per share)	$ 77.41	$ 74.77	$ 73.03
Granted, Weighted Average Grant Date Fair Value (in dollars per share)	71.78	81.74	76.49
Vested, Weighted Average Grant Date Fair Value (in dollars per share)	73.54	74.39	71.75
Cancelled and forfeited, Weighted Average Grant Date Fair Value (in dollars per share)	75.57	81.59	77.16
Nonvested ending, Weighted Average Grant Date Fair Value (in dollars per share)	$ 76.65	$ 77.41	$ 74.77

Dividend Restrictions (Narrativ

Dividend Restrictions (Narrative) (Detail) - Virginia Power and PSNC	12 Months Ended
	Dec. 31, 2021
Dividend Restrictions [Line Items]
Regulatory restrictions on payment of dividends	In addition, notice to the North Carolina Commission is required if payment of dividends causes the equity component of Virginia Power and PSNC’s capital structure to fall below 45%.
Required equity capital percentage	45.00%

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Detail) - USD ($)		1 Months Ended		3 Months Ended					12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2020	Sep. 30, 2019	Jun. 30, 2019	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Accumulated benefit obligation		$ 10,200,000,000	$ 10,600,000,000	$ 10,200,000,000	$ 10,600,000,000					$ 10,200,000,000	$ 10,600,000,000
Contributions to qualified defined benefit pension plans, shares												6,100,000
Defined contribution plan, employer matching contributions										65,000,000	67,000,000	$ 69,000,000
Discontinued Operations
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost										$ 1,000,000	13,000,000	16,000,000
Common and Preferred Stocks
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages		27.00%		27.00%						27.00%
Non-U.S. Equity
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages		18.00%		18.00%						18.00%
Fixed Income Funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages		32.00%		32.00%						32.00%
Real Estate Funds
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages		3.00%		3.00%						3.00%
Other than Securities Investment
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined benefit plan, actual plan asset allocation percentages		20.00%		20.00%						20.00%
Common Stock
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions to qualified defined benefit pension plans												499,000,000
Series C Preferred Stock
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Issued to qualified defined benefit pension plans, shares		250,000
Virginia Electric and Power Company
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Amounts due to Dominion		$ 121,000,000	266,000,000	$ 121,000,000	266,000,000					$ 121,000,000	266,000,000
Defined contribution plan, employer matching contributions										20,000,000	19,000,000	20,000,000
BHE
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contribution to voluntary employees beneficiary association												12,000,000
Pension Plans and Post Retirement Benefit Plan
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on pension and other postretirement plan assets										1,500,000,000	1,900,000,000
Expected return on pension and other postretirement plan assets										1,000,000,000	933,000,000
Curtailment resulted in a decrease in the pension benefit obligation				26,000,000
Increase to net periodic benefit cost (credit)				$ 2,000,000
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on pension and other postretirement plan assets										1,202,000,000	1,602,000,000
Expected return on pension and other postretirement plan assets										834,000,000	777,000,000	708,000,000
Increase to net periodic benefit cost (credit)										(144,000,000)	(32,000,000)	93,000,000
Increase (decrease) in fair value of plan assets							$ 51,000,000	$ 671,000,000
Actuarial gains (losses) from increase decrease in discount rate										413,000,000	(1,000,000,000)
Contributions to qualified defined benefit pension plans			250,000,000							284,000,000	278,000,000	520,000,000
Service cost										170,000,000	173,000,000	162,000,000
Pension Benefits | Series C Preferred Stock
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions to qualified defined benefit pension plans		$ 250,000,000
Pension Benefits | Virginia Electric and Power Company | Amounts Associated With Dominion Pension Plan
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Payment made to Dominion										175,000,000	313,000,000	0
Amounts due to Dominion			$ 151,000,000		$ 151,000,000						151,000,000
Pension Benefits | Virginia Electric and Power Company | Other Operations and Maintenance
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase to net periodic benefit cost (credit)										$ 86,000,000	$ 118,000,000	152,000,000
Pension Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage		3.06%	2.73%	3.06%	2.73%			4.07%		3.06%	2.73%
Pension Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage		3.19%	2.95%	3.19%	2.95%			4.10%		3.19%	2.95%
Pension Benefits | BHE
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase to net periodic benefit cost (credit)											$ (4,000,000)
Remeasurement resulted in increase in pension benefit obligation						$ 497,000,000
Increase (decrease) in fair value of plan assets						$ (87,000,000)
Pension Benefits | BHE | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage			3.11%		3.11%						3.11%
Pension Benefits | BHE | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage			3.16%		3.16%						3.16%
Other Postretirement Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actual return (loss) on pension and other postretirement plan assets										$ 294,000,000	$ 300,000,000
Expected return on pension and other postretirement plan assets										173,000,000	156,000,000	140,000,000
Increase to net periodic benefit cost (credit)										$ (140,000,000)	$ (172,000,000)	$ (46,000,000)
Increase (decrease) in fair value of plan assets								$ 156,000,000
Health care cost trend rate	[1]	6.25%	6.25%	6.25%	6.25%					6.25%	6.25%
Health care cost trend decreased rate	[1]	5.00%	5.00%	5.00%	5.00%					5.00%	5.00%	5.00%
Actuarial gains (losses) from increase decrease in discount rate										$ 161,000,000	$ (149,000,000)
Actuarial gain from completed experience study and update to healthcare claim assumptions											85,000,000
Contributions to qualified defined benefit pension plans											13,000,000
Contribution to voluntary employees beneficiary association										0
Service cost										25,000,000	28,000,000	$ 26,000,000
Other Postretirement Benefits | Virginia Electric and Power Company
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contribution to voluntary employees beneficiary association										0	0	0
Other Postretirement Benefits | Virginia Electric and Power Company | Forecast
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contribution to voluntary employees beneficiary association									$ 0
Other Postretirement Benefits | Virginia Electric and Power Company | Other Operations and Maintenance | Dominion Energy Retiree Health And Welfare Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase to net periodic benefit cost (credit)										$ (72,000,000)	$ (58,000,000)	$ (27,000,000)
Other Postretirement Benefits | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage		3.04%	2.69%	3.04%	2.69%			4.05%		3.04%	2.69%
Health care cost trend rate	[1]											6.50%
Other Postretirement Benefits | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage		3.11%	2.80%	3.11%	2.80%			4.08%		3.11%	2.80%
Health care cost trend rate	[1]											6.60%
Other Postretirement Benefits | BHE
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Increase (decrease) in fair value of plan assets					$ (25,000,000)
Increase in accumulated postretirement benefit obligation					$ 16,000,000
Health care cost trend rate			6.25%		6.25%						6.25%
Health care cost trend decreased rate			5.00%		5.00%						5.00%
Other Postretirement Benefits | BHE | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage			3.07%		3.07%						3.07%
Other Postretirement Benefits | BHE | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Discount rate percentage			3.11%		3.11%						3.11%
Voluntary Retirement Program
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Remeasurement resulted in increase in pension benefit obligation							$ 37,000,000	$ 484,000,000
Discount rate percentage							3.57%
Increase in accumulated postretirement benefit obligation								$ 101,000,000
Voluntary retirement program related charges												$ 427,000,000
Voluntary retirement program related charges net of tax												319,000,000
Voluntary Retirement Program | Other Operations and Maintenance
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												251,000,000
Voluntary Retirement Program | Other Taxes
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												21,000,000
Voluntary Retirement Program | Other Income
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												111,000,000
Voluntary Retirement Program | Net Income Including Noncontrolling Interest From Discontinued Operations
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												44,000,000
Voluntary Retirement Program | Virginia Electric and Power Company
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												198,000,000
Voluntary retirement program related charges net of tax												146,000,000
Voluntary Retirement Program | Virginia Electric and Power Company | Other Operations and Maintenance
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												190,000,000
Voluntary Retirement Program | Virginia Electric and Power Company | Other Taxes
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Voluntary retirement program related charges												$ 8,000,000
[1]	Assumptions used to determine net periodic cost for the following year.

Employee Benefit Plans (Summary

Employee Benefit Plans (Summary of Changes in Pension and Other Postretirement Benefit Plans) (Detail) - USD ($) $ in Millions		1 Months Ended	12 Months Ended
		Dec. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jun. 30, 2019
Amounts recognized in the Consolidated Balance Sheets at December 31:
Noncurrent pension and other postretirement benefit assets		$ 1,704	$ 2,310	$ 1,704
Noncurrent pension and other postretirement benefit liabilities		(1,706)	(442)	(1,706)
Pension Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year			11,363	10,446
Service cost			170	173	$ 162
Interest cost			317	351	394
Benefits paid			(488)	(461)
Actuarial (gains) losses during the year			(413)	992
Settlements and curtailments	[1]		59	138
Benefit obligation at end of year		11,363	10,890	11,363	10,446
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year			10,979	9,631
Actual return (loss) on plan assets			1,202	1,602
Employer contributions		250	284	278	520
Benefits paid			(488)	(461)
Settlements	[2]		(32)	(71)
Fair value of plan assets at end of year		10,979	11,945	10,979	9,631
Funded status at end of year		(384)	1,055	(384)
Amounts recognized in the Consolidated Balance Sheets at December 31:
Noncurrent pension and other postretirement benefit assets		1,054	1,246	1,054
Other current liabilities		(14)	(12)	(14)
Noncurrent pension and other postretirement benefit liabilities		(1,424)	(179)	(1,424)
Net amount recognized		$ (384)	$ 1,055	$ (384)
Significant assumptions used to determine benefit obligations as of December 31:
Weighted average rate of increase for compensation		4.53%	4.51%	4.53%
Pension Benefits | Minimum
Significant assumptions used to determine benefit obligations as of December 31:
Discount rate		2.73%	3.06%	2.73%		4.07%
Crediting interest rate for cash balance and similar plans		1.93%	1.81%	1.93%
Crediting interest rate for cash balance and similar plans		1.93%	1.81%	1.93%
Pension Benefits | Maximum
Significant assumptions used to determine benefit obligations as of December 31:
Discount rate		2.95%	3.19%	2.95%		4.10%
Crediting interest rate for cash balance and similar plans		2.15%	1.94%	2.15%
Crediting interest rate for cash balance and similar plans		2.15%	1.94%	2.15%
Other Postretirement Benefits
Changes in benefit obligation:
Benefit obligation at beginning of year			$ 1,746	$ 1,769
Service cost			25	28	26
Interest cost			46	58	68
Benefits paid			(105)	(120)
Actuarial (gains) losses during the year			(161)	33
Plan amendments			(14)	(6)
Settlements and curtailments	[1]			16
Benefit obligation at end of year		$ 1,746	1,537	1,746	1,769
Changes in fair value of plan assets:
Fair value of plan assets at beginning of year			2,100	1,880
Actual return (loss) on plan assets			294	300
Employer contributions				13
Benefits paid			(71)	(93)
Fair value of plan assets at end of year		2,100	2,323	2,100	$ 1,880
Funded status at end of year		354	786	354
Amounts recognized in the Consolidated Balance Sheets at December 31:
Noncurrent pension and other postretirement benefit assets		650	1,064	650
Other current liabilities		(15)	(15)	(15)
Noncurrent pension and other postretirement benefit liabilities		(281)	(263)	(281)
Net amount recognized		$ 354	$ 786	$ 354
Other Postretirement Benefits | Minimum
Significant assumptions used to determine benefit obligations as of December 31:
Discount rate		2.69%	3.04%	2.69%		4.05%
Other Postretirement Benefits | Maximum
Significant assumptions used to determine benefit obligations as of December 31:
Discount rate		2.80%	3.11%	2.80%		4.08%
[1]	2021 amounts include curtailments and settlements recognized primarily as a result of the employee choice program and settlements of nonqualified pension obligations. 2020 amounts include curtailment and settlements recognized as a result of the GT&S Transaction as well as settlements of qualified and nonqualified pension obligations.
[2]	2021 amounts relate to settlements of nonqualified pension obligations and 2020 amounts relate primarily to settlements of qualified and nonqualified pension obligations.

Employee Benefit Plans (Benefit

Employee Benefit Plans (Benefit Obligation in Excess of Plan Assets) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	$ 9,420	$ 10,697
Fair value of plan assets	9,229	9,259
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation	261	305
Fair value of plan assets	$ 7	$ 9

Employee Benefit Plans (Accumul

Employee Benefit Plans (Accumulated Benefit Obligation in Excess of Plan Assets) (Detail) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
General Discussion Of Pension And Other Postretirement Benefits [Abstract]
Accumulated benefit obligation	$ 127	$ 9,970
Fair value of plan assets	$ 53	$ 9,259

Employee Benefit Plans (Benef_2

Employee Benefit Plans (Benefit Payments Expected Future Service) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
2022	$ 513
2023	516
2024	529
2025	541
2026	548
2027-2031	2,833
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
2022	101
2023	100
2024	99
2025	97
2026	96
2027-2031	$ 450

Employee Benefit Plans (Fair Va

Employee Benefit Plans (Fair Values of Pension and Post Retirement Plan Assets by Asset Category) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[1]	$ 11,945	$ 10,831
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[2]	2,319	2,091
Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4,510	4,214
Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,164	1,061
Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2,900	2,567
Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		140	127
Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		7,410	6,781
Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,304	1,188
NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	4,535	4,050
Cash equivalents and other | Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		25	20
Cash equivalents and other | Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		3
Cash equivalents and other | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		5	1
Cash equivalents and other | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1	2
Cash equivalents and other | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		30	21
Cash equivalents and other | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		4	2
US Equity Securities | Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[4]	2,592	2,405
US Equity Securities | Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		898	817
US Equity Securities | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[4]	244
US Equity Securities | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		14
US Equity Securities | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[4]	2,836	2,405
US Equity Securities | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		912	817
Foreign Equity Securities | Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,773	1,727
Foreign Equity Securities | Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		256	240
Foreign Equity Securities | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		19
Foreign Equity Securities | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1
Foreign Equity Securities | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,792	1,727
Foreign Equity Securities | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		257	240
Insurance Contracts | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		279	409
Insurance Contracts | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		16	23
Insurance Contracts | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		279	409
Insurance Contracts | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		16	23
Corporate debt instruments | Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		81	32
Corporate debt instruments | Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		5	2
Corporate debt instruments | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,439	1,385
Corporate debt instruments | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		61	60
Corporate debt instruments | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		1,520	1,417
Corporate debt instruments | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		66	62
Government securities | Level 1 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		39	30
Government securities | Level 1 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		2	2
Government securities | Level 2 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		914	772
Government securities | Level 2 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		47	42
Government securities | Fair Value, Inputs, Level 1, 2 and 3 | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		953	802
Government securities | Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value		49	44
Common/collective trust funds | NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	3,010	2,905
Common/collective trust funds | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	840	765
Real Estate Funds | NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	116	108
Real Estate Funds | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	13	10
Private Equity Funds | NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	1,233	856
Private Equity Funds | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	152	117
Fixed Income Funds | NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	162	168
Fixed Income Funds | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	9	10
Hedge Funds | NAV | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	14	13
Hedge Funds | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	1	1
Investments Measured At Fair Value Including Excluding Pending Purchases Sales And Accrued Income | NAV | Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total recorded at fair value	[3]	$ 1,015	$ 903
[1]	Excludes net assets related to pending sales of securities of $35 million, net accrued income of $27
[2]	Excludes net assets related to pending sales of securities of $5 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $3 million at December 31, 2021. Excludes net assets related to pending sales of securities of $10 million, net accrued income of $2 million, and includes net assets related to pending purchases of securities of $2 million at December 31, 2020.
[3]	These investments that are measured at fair value using the NAV per share (or its equivalent) as a practical expedient are not required to be categorized in the fair value hierarchy.
[4]	Includes $258 million of Dominion Energy preferred stock and no Dominion Energy common stock at December 31, 2021 and $365 million of Dominion Energy common stock at December 31, 2020.

Employee Benefit Plans (Fair _2

Employee Benefit Plans (Fair Values of Pension and Post Retirement Plan Assets by Asset Category) (Parenthetical) (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Common stock	$ 0	$ 365,000,000
Preferred stock	258,000,000
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pending sales of securities	35,000,000
Pending sales of securities and advanced subscriptions		198,000,000
Net accrued income	27,000,000	20,000,000
Pending purchases of securities	62,000,000	71,000,000
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Pending sales of securities	5,000,000	10,000,000
Net accrued income	2,000,000	2,000,000
Pending purchases of securities	$ 3,000,000	$ 2,000,000

Employee Benefit Plans (Net Per

Employee Benefit Plans (Net Periodic Benefit (Credit) Cost and Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits
Service cost		$ 170	$ 173	$ 162
Interest cost		317	351	394
Expected return on plan assets		(834)	(777)	(708)
Amortization of prior service (credit) cost			1	1
Amortization of net actuarial loss		193	206	172
Settlements, curtailments and special termination benefits		10	14	72
Net periodic benefit (credit) cost		(144)	(32)	93
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		(782)	166	16
Settlements and curtailments		(36)	(81)	6
Amortization of net actuarial loss		(193)	(206)	(172)
Amortization of prior service credit (cost)			(1)	(1)
Total recognized in other comprehensive income and regulatory assets and liabilities		$ (1,011)	$ (122)	$ (151)
Significant assumptions used to determine periodic cost:
Weighted average rate of increase for compensation		4.53%	4.23%	4.20%
Pension Benefits | Minimum
Significant assumptions used to determine periodic cost:
Discount rate		2.73%	2.77%	3.57%
Expected long-term rate of return on plan assets		7.00%	7.00%	7.00%
Crediting interest rate for cash balance and similar plans		1.93%	2.31%	2.77%
Pension Benefits | Maximum
Significant assumptions used to determine periodic cost:
Discount rate		3.29%	3.63%	4.43%
Expected long-term rate of return on plan assets		8.45%	8.60%	8.65%
Crediting interest rate for cash balance and similar plans		2.15%	2.83%	3.63%
Other Postretirement Benefits
Service cost		$ 25	$ 28	$ 26
Interest cost		46	58	68
Expected return on plan assets		(173)	(156)	(140)
Amortization of prior service (credit) cost		(42)	(49)	(52)
Amortization of net actuarial loss		4	6	10
Settlements, curtailments and special termination benefits			(59)	42
Net periodic benefit (credit) cost		(140)	(172)	(46)
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss		(282)	(110)	(98)
Prior service (credit) cost		(13)	(6)	2
Settlements and curtailments			59
Amortization of net actuarial loss		(4)	(6)	(10)
Amortization of prior service credit (cost)		42	49	52
Total recognized in other comprehensive income and regulatory assets and liabilities		$ (257)	$ (14)	$ (54)
Significant assumptions used to determine periodic cost:
Expected long-term rate of return on plan assets		8.45%	8.50%	8.50%
Health care cost trend rate	[1]	6.25%	6.25%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	[1]	5.00%	5.00%	5.00%
Other Postretirement Benefits | Minimum
Significant assumptions used to determine periodic cost:
Discount rate		2.69%	3.07%	4.05%
Health care cost trend rate	[1]			6.50%
Year that the rate reaches the ultimate trend rate	[1]	2026	2025	2023
Other Postretirement Benefits | Maximum
Significant assumptions used to determine periodic cost:
Discount rate		2.80%	3.52%	4.41%
Health care cost trend rate	[1]			6.60%
Year that the rate reaches the ultimate trend rate	[1]	2027	2026	2025
[1]	Assumptions used to determine net periodic cost for the following year.

Employee Benefit Plans (AOCI an

Employee Benefit Plans (AOCI and Regulatory Assets and Liabilities that have Not been Recognized as Components of Periodic Benefit (Credit) Cost) (Detail) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		$ 1,458	$ 1,717
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		2,198	3,207
Prior service (credit) cost		2	4
Total	[1]	2,200	3,211
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss		(166)	120
Prior service (credit) cost		(203)	(232)
Total	[1]	$ (369)	$ (112)
[1]	As of December 31, 2021, of the $2.2 billion and $(369) million related to pension benefits and other postretirement benefits, $1.7 billion and $(155) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2020,

Employee Benefit Plans (AOCI _2

Employee Benefit Plans (AOCI and Regulatory Assets and Liabilities that have Not been Recognized as Components of Periodic Benefit (Credit) Cost) (Parenthetical) (Detail) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[1]	$ 2,200	$ 3,211
Amount included in AOCI		1,700	1,900
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	[1]	(369)	(112)
Amount included in AOCI		$ (155)	$ (40)
[1]	As of December 31, 2021, of the $2.2 billion and $(369) million related to pension benefits and other postretirement benefits, $1.7 billion and $(155) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2020,

Commitments and Contingencies_2

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

1 Months Ended

12 Months Ended

Aug. 31, 2021shares

Jul. 31, 2021USD ($)shares

Jun. 30, 2021USD ($)

Dec. 31, 2020USD ($)

Oct. 31, 2020

Sep. 30, 2020USD ($)

Aug. 31, 2020USD ($)

Jul. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Jul. 31, 2019USD ($)

Aug. 31, 2018USD ($)

Jun. 30, 2018USD ($)

Aug. 31, 2017USD ($)

Apr. 30, 2017Petition

Aug. 31, 2016T

Dec. 31, 2021USD ($)FacilityIndicatorsitegal

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Mar. 31, 2020USD ($)

Loss Contingencies [Line Items]

Impairment of assets and other charges

$ 195

$ 2,105

$ 1,520

Property, plant and equipment, net

$ 57,848

59,774

57,848

Common Stock

Loss Contingencies [Line Items]

Litigation settlement, benefit fund

$ 320

Litigation settlement amount through stock issuance

$ 322

DESC Ratepayer Case

Loss Contingencies [Line Items]

Litigation settlement, benefit fund

$ 520

SCANA

Loss Contingencies [Line Items]

Other expense

25

Other expense, after tax

25

Impairment of assets and other charges

100

90

641

Impairment of assets and other charges, after tax

75

68

$ 480

Escrow account

$ 160

Litigation settlement expense

$ 32.5

$ 192.5

Litigation settlement paid

25

SCANA | DESC Ratepayer Case

Loss Contingencies [Line Items]

Escrow account

$ 2,000

Credit in future electric rate relief

2,000

Cash payment

$ 117

115

Proceeds from sale of property

38.5

Property, plant and equipment, net

$ 3

$ 27

8

SCANA | State Court Derivative Case

Loss Contingencies [Line Items]

Litigation settlement paid

$ 33

SCANA | Federal Court Merger Case | State Court Merger Case

Loss Contingencies [Line Items]

Litigation settlement paid

63

SCANA | Other Current Liabilities

Loss Contingencies [Line Items]

Reserves for SCANA legal proceedings

208

274

208

SCANA | Other Receivables

Loss Contingencies [Line Items]

Insurance receivables

8

118

8

DESC

Loss Contingencies [Line Items]

Litigation settlement expense

$ 99

SCANA and DESC

Loss Contingencies [Line Items]

Disgorgement and prejudgment interest total, amount

112.5

Minimum | SCANA | DESC Ratepayer Case

Loss Contingencies [Line Items]

Proceeds from sale of property

60

Maximum | SCANA | Common Stock

Loss Contingencies [Line Items]

Litigation settlement amount through stock issuance

$ 32.5

Maximum | SCANA | DESC Ratepayer Case

Loss Contingencies [Line Items]

Proceeds from sale of property

$ 85

Virginia Electric and Power Company

Loss Contingencies [Line Items]

Property, plant and equipment, net

32,569

$ 34,656

32,569

Virginia Electric and Power Company | Environmental Protection Agency And State Regulatory Agencies

Loss Contingencies [Line Items]

Number of facilities to assess the applicability of section 316(b) | Facility

3

Hydroelectric Facilities | Environmental Protection Agency And State Regulatory Agencies

Loss Contingencies [Line Items]

Number of facilities to assess the applicability of section 316(b) | Facility

8

Dominion Energy South Carolina Inc | NND Project

Loss Contingencies [Line Items]

Noncontrolling partnership interest

55.00%

Contested amount for filed liens in Fairfield country

$ 285

Dominion Energy South Carolina Inc | SCDOR

Loss Contingencies [Line Items]

Litigation settlement paid

165

Proposed assessment amount from audit

$ 410

Proportional share of NND project

100.00%

Dominion Energy South Carolina Inc | South Carolina

Loss Contingencies [Line Items]

Amount claimed by plaintiffs in legal matter

$ 100

Percentage claimed by plaintiffs in legal matter

100.00%

Dominion Energy South Carolina Inc | DESC | Common Stock

Loss Contingencies [Line Items]

Litigation settlement through stock issuance | shares

1.4

Dominion Energy South Carolina Inc | DESC | Common Stock | SCDOR

Loss Contingencies [Line Items]

Initial litigation settlement through stock issuance | shares

0.6

Dominion Energy South Carolina Inc | Minimum | SCDOR

Loss Contingencies [Line Items]

Initial litigation settlement amount through stock issuance

$ 43

Unfavorable Regulatory Action | EPA

Loss Contingencies [Line Items]

Electric generating station facilities heightened entrainment analysis per day | gal

125,000,000

Personal Injury or Wrongful Death Cases | SCANA

Loss Contingencies [Line Items]

Reserves for SCANA legal proceedings

8

$ 85

8

Insurance receivables

$ 8

$ 85

8

Carbon Regulations

Loss Contingencies [Line Items]

Public Utilities Significant Emission Rate Per Year CO2 Equivalent | T

75,000

CWA | Unfavorable Regulatory Action

Loss Contingencies [Line Items]

Number of mandatory facility-specific factors | Indicator

5

Number of optional facility-specific factors | Indicator

6

Number of facilities that are subject to final regulations | Facility

15

CWA | Unfavorable Regulatory Action | Minimum

Loss Contingencies [Line Items]

Electric generating stations with water withdrawals per day | gal

2,000,000

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

Loss Contingencies [Line Items]

Number of separate petitions for reconsideration granted | Petition

2

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

Loss Contingencies [Line Items]

Loss contingencies individual circumstances period

2021

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

Loss Contingencies [Line Items]

Loss contingencies individual circumstances period

2028

CWA | Unfavorable Regulatory Action | Virginia Electric and Power Company

Loss Contingencies [Line Items]

Number of facilities that are subject to final regulations | Facility

9

Waste Management and Remediation | Unfavorable Regulatory Action | EPA

Loss Contingencies [Line Items]

Number of sites remediation work substantially completed | site

13

Number of sites with remediation plans | site

2

Environmental remediation reserves

$ 11

Environmental remediation expense

14

Environmental remediation expense net of tax

11

Number of sites with an updated work plan | site

1

Number of additional sites which are not under investigation | site

12

Waste Management and Remediation | Unfavorable Regulatory Action | EPA | Former Gas Plant Site With Post Closure Groundwater Monitoring Program

Loss Contingencies [Line Items]

Environmental remediation reserves

$ 45

42

Waste Management and Remediation | Unfavorable Regulatory Action | Virginia Electric and Power Company | EPA

Loss Contingencies [Line Items]

Number of sites with remediation plans | site

1

Environmental remediation expense

10

Environmental remediation expense net of tax

7

Number of additional sites which are not under investigation | site

2

Waste Management and Remediation | Unfavorable Regulatory Action | Virginia Electric and Power Company | EPA | Former Gas Plant Site With Post Closure Groundwater Monitoring Program

Loss Contingencies [Line Items]

Environmental remediation reserves

$ 25

$ 26

Commitments and Contingencies_3

Commitments and Contingencies (Nuclear Operations) (Narrative) (Detail) - USD ($)	1 Months Ended					3 Months Ended	12 Months Ended
	Feb. 28, 2022	Jun. 30, 2021	May 31, 2021	Feb. 28, 2021	Mar. 31, 2015	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Minimum financial assurance							$ 3,200,000,000
NRC minimum requirement for nuclear power plant licensees							1,060,000,000
Maximum assessment for premiums on insurance policy							33,000,000
Maximum assessment for insurance policy							76,000,000
Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables							52,000,000	$ 46,000,000
Forecast
Loss Contingencies [Line Items]
Settlement amount awarded from other party	$ 48,000,000
Maximum
Loss Contingencies [Line Items]
Amount that could be assessed for each licensed reactor							138,000,000
Amount that could be assessed for each licensed reactor per reactor							21,000,000
Millstone, Summer, Surry and North Anna
Loss Contingencies [Line Items]
Amount of coverage purchased from commercial insurance pools							450,000,000
Kewaunee
Loss Contingencies [Line Items]
Maximum assessment for premiums on insurance policy					$ 50,000,000
Surry and North Anna
Loss Contingencies [Line Items]
Settlement amount awarded from other party							25,000,000	24,000,000	$ 15,000,000
Millstone
Loss Contingencies [Line Items]
Settlement amount awarded from other party							9,000,000	11,000,000	11,000,000
Summer
Loss Contingencies [Line Items]
Settlement amount awarded from other party							1,000,000	4,000,000	$ 3,000,000
Nuclear Obligations
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount							13,500,000,000
Nuclear Obligations | Secondary Financial Protection Program
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount		$ 13,500,000,000	$ 13,700,000,000	$ 13,800,000,000		$ 13,700,000,000
Nuclear Obligations | Kewaunee
Loss Contingencies [Line Items]
Maximum liability protection per nuclear incident amount							100,000,000
Virginia Electric and Power Company
Loss Contingencies [Line Items]
Minimum financial assurance							1,900,000,000
Maximum assessment for premiums on insurance policy							35,000,000
Maximum assessment for insurance policy							9,000,000
Virginia Electric and Power Company | Spent Nuclear Fuel
Loss Contingencies [Line Items]
Receivables							39,000,000	$ 35,000,000
DESC | Non-nuclear Obligation | European Mutual Association
Loss Contingencies [Line Items]
Property insurance coverage							415,000,000
Annual Premium							$ 2,000,000

Commitments and Contingencies_4

Commitments and Contingencies (Nuclear Insurance) (Detail) $ in Millions	Dec. 31, 2021USD ($)
Millstone
Guarantee Obligations [Line Items]
Property insurance coverage	$ 1,060
Kewaunee
Guarantee Obligations [Line Items]
Property insurance coverage	50
Summer
Guarantee Obligations [Line Items]
Property insurance coverage	2,750
Surry | Virginia Electric and Power Company
Guarantee Obligations [Line Items]
Property insurance coverage	1,060
North Anna | Virginia Electric and Power Company
Guarantee Obligations [Line Items]
Property insurance coverage	$ 1,060

Commitments and Contingencies_5

Commitments and Contingencies (Schedule of Long Term Purchase Commitments) (Detail) - Purchased electric capacity $ in Millions	Dec. 31, 2021USD ($)	[1]
Long-term Purchase Commitment [Line Items]
2022	$ 66
2023	66
2024	66
2025	65
2026	68
Thereafter	681
Total	$ 1,012
[1]	Commitments represent estimated amounts payable for energy under power purchase contracts with qualifying facilities which expire at various dates through 2046. Energy payments are generally based on fixed dollar amounts per month and totaled $59 million and $52 million for the years ended December 31, 2021 and 2020, respectively.

Commitments and Contingencies_6

Commitments and Contingencies (Schedule of Long Term Purchase Commitments) (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Power Purchase Contracts [Abstract]
Energy payments	$ 59	$ 52

Commitments and Contingencies_7

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Detail)	12 Months Ended
	Dec. 31, 2021USD ($)Guarantee
Guarantee Obligations [Line Items]
Guarantee liability	$ 3,923,000,000	[1]
Financial Guarantee | Equity Method Investee | Cove Point
Guarantee Obligations [Line Items]
Number of Guarantee | Guarantee	4
Guarantees with Maximum Limit [Member] | Equity Method Investee | Cove Point
Guarantee Obligations [Line Items]
Number of Guarantee | Guarantee	2
Guarantee liability	$ 1,900,000,000
Guarantees with No Maximum Limit [Member] | Equity Method Investee | Cove Point
Guarantee Obligations [Line Items]
Number of Guarantee | Guarantee	2
Guarantee liability	$ 0
Additional Guarantees [Member]
Guarantee Obligations [Line Items]
Guarantee liability	20,000,000
Surety Bond
Guarantee Obligations [Line Items]
Guarantee liability	217,000,000
Surety Bond | Virginia Electric and Power Company
Guarantee Obligations [Line Items]
Guarantee liability	154,000,000
Financial Standby Letter of Credit
Guarantee Obligations [Line Items]
Guarantee liability	$ 131,000,000
[1]	Excludes Dominion Energy’s guarantees for the new corporate office property and an offshore wind installation vessel discussed in Note 15.

Commitments and Contingencies -

Commitments and Contingencies - (Schedule of Subsidiary Guarantees) (Detail)	Dec. 31, 2021USD ($)
Guarantee Obligations [Line Items]
Maximum Exposure	$ 3,923,000,000	[1]
Commodity Transactions
Guarantee Obligations [Line Items]
Maximum Exposure	2,077,000,000	[2]
Nuclear Obligations
Guarantee Obligations [Line Items]
Maximum Exposure	243,000,000	[3]
Solar
Guarantee Obligations [Line Items]
Maximum Exposure	321,000,000	[4]
Other
Guarantee Obligations [Line Items]
Maximum Exposure	$ 1,282,000,000	[5]
[1]	Excludes Dominion Energy’s guarantees for the new corporate office property and an offshore wind installation vessel discussed in Note 15.
[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 primarily related to certain DGI subsidiaries regarding all aspects of running a nuclear facility.
[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. Also includes guarantees entered into by Dominion Energy RNG Holdings, II, Inc. on behalf of a subsidiary to facilitate construction of renewable natural gas facilities. Due to the uncertainty of workers’ compensation claims, the parental guarantee has no stated limit.

Commitments and Contingencies_8

Commitments and Contingencies (Charitable Commitments) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2021
Other Deferred Credits and Other Liabilities
Recorded Unconditional Purchase Obligation [Line Items]
Charitable commitments	$ 73	$ 43
Other Current Liabilities
Recorded Unconditional Purchase Obligation [Line Items]
Charitable commitments		$ 26
Other Income
Recorded Unconditional Purchase Obligation [Line Items]
Charitable expenses	$ 80

Credit Risk (Narrative) (Detail

Credit Risk (Narrative) (Detail)	12 Months Ended
	Dec. 31, 2021USD ($)counterparty	Dec. 31, 2020USD ($)
Concentration Risk and Guarantor Obligations [Line Items]
Credit exposure	$ 152,000,000
Additional collateral to be posted if the credit related contingent features were triggered	31,000,000	$ 14,000,000
Collateral derivatives with credit-related contingent provision in a liability position	66,000,000	1,000,000
Aggregate fair value of all derivative instruments with credit contingent provisions that are in a liability position	97,000,000	15,000,000
Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Credit exposure	16,000,000
Additional collateral to be posted if the credit related contingent features were triggered	22,000,000	2,000,000
Collateral derivatives with credit-related contingent provision in a liability position	54,000,000	0
Aggregate fair value of all derivative instruments with credit contingent provisions that are in a liability position	76,000,000	$ 2,000,000
Credit Concentration Risk
Concentration Risk and Guarantor Obligations [Line Items]
Amount of exposure for single counterparty	$ 45,000,000
Number of counterparties | counterparty	0
Credit Concentration Risk | Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Amount of exposure for single counterparty	$ 4,000,000
Number of counterparties | counterparty	0
Credit Concentration Risk | Investment Grade Counterparty | Virginia Electric and Power Company
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	47.00%
Credit Concentration Risk | Investment Grade | Investment Grade Counterparty
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	85.00%

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Detail) - USD ($)	1 Months Ended				12 Months Ended
	Aug. 31, 2021	Jul. 31, 2021	Sep. 30, 2020	Aug. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Derivative asset					$ 613,000,000	$ 397,000,000
Derivative liabilities					868,000,000	486,000,000
Issuance of common stock (in shares)	600,000	1,400,000	4,100,000	18,500,000			6,100,000
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Derivative asset					300,000,000	181,000,000
Derivative liabilities					470,000,000	405,000,000
Payable to affiliates					699,000,000	380,000,000
Outstanding borrowings, net of repayments, under money pool for non-regulated subsidiaries					$ 0	$ 0
Issuance of common stock (in shares)					0	0	0
Virginia Electric and Power Company | Pension Benefits | Amounts Associated With Dominion Pension Plan
Related Party Transaction [Line Items]
Amounts due to Dominion, noncurrent					$ 522,000,000	$ 436,000,000
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					431,000,000	354,000,000
Virginia Electric and Power Company | Affiliated Entity
Related Party Transaction [Line Items]
Derivative asset					29,000,000	3,000,000
Derivative liabilities					6,000,000	22,000,000
Virginia Electric and Power Company | Principal Owner | Short-Term Borrowing Arrangements
Related Party Transaction [Line Items]
Payable to affiliates					$ 699,000,000	$ 380,000,000
Weighted- average interest rate percentage					0.26%	0.30%

Related-Party Transactions (Det

Related-Party Transactions (Detail) - Virginia Electric and Power Company - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Commodity purchases from affiliates		$ 742	$ 569	$ 690
Services provided by affiliates	[1]	494	455	503
Affiliated Entity
Related Party Transaction [Line Items]
Services provided to affiliates		$ 18	$ 18	$ 24
[1]	Includes capitalized expenditures of $161 million, $141 million and $133 million for the year ended December 31, 2021, 2020 and 2019, respectively.

Related-Party Transactions (Par

Related-Party Transactions (Parenthetical) (Detail) - Virginia Electric and Power Company - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Capital expenditures	$ 3,521	$ 3,138	$ 2,642
Services provided by affiliates | Affiliated Entity
Related Party Transaction [Line Items]
Capital expenditures	$ 161	$ 141	$ 133

Operating Segments - Dominion E

Operating Segments - Dominion Energy (Narrative) (Detail) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Aug. 31, 2020	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2019
Segment Reporting Information [Line Items]
Gain (loss) on investments			$ 639	$ 412	$ 626
Asset early retirement expense			165	114
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Asset early retirement expense			131	85
SCANA
Segment Reporting Information [Line Items]
Litigation settlement expense	$ 32.5	$ 192.5
Merger and integration-related costs					427
Merger and integration-related costs, after tax					320
Charge related to a voluntary retirement program					394
Charge related to a voluntary retirement program, after-tax					295
Operating Segments
Segment Reporting Information [Line Items]
After-tax net expense (income)			493	1,200	1,900
Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After-tax net expense (income)			202	863
Benefit for change in expected CCRO reserve			130
Benefit for change in expected CCRO reserve, after tax			97
Charges associated with budget process related to customer arrears			77
Charges associated with budget process related to customer arrears, after tax			57
Charge associated with storm damage and service restoration			68
Charge associated with storm damage and service restoration, after tax			50
Amortization of regulatory asset			61
Amortization of regulatory asset after tax			45
Loss from unbilled revenue reduction			151
Loss from unbilled revenue reduction, after tax			112
Net charge associated with settlement of the 2021 Triennial Review			125
Net charge associated with settlement of the 2021 Triennial Review, after tax			93
Asset early retirement expense after tax				559	257
Charge for expected CCRO				130
Charge for expected CCRO, net of tax				97
Charges associated with legislation enacted related to customer arrears				127
Charges associated with legislation enacted related to customer arrears, net of tax				94
Charge related to a voluntary retirement program					198
Charge related to a voluntary retirement program, after-tax					146
Benefit from revision of future closure costs					113
Benefit from revision of future closure costs, after tax					84
Operating Segments | Nuclear Decommissioning Trust Funds
Segment Reporting Information [Line Items]
Gain (loss) on investments			568	335	553
Gain (loss) on investments, after tax			445	264	411
Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
After-tax net expense (income)			99	3,700	1,800
After- tax net expense (income) for specific items			(97)	3,400	1,500
Corporate and Other | Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After-tax net expense (income)			202	863	634
After- tax net expense (income) for specific items			202	915	627
Contracted Assets | SCANA
Segment Reporting Information [Line Items]
Charge related to a voluntary retirement program, after-tax					38
Contracted Assets | Operating Segments
Segment Reporting Information [Line Items]
Loss related to economic hedging activities			347
Loss related to economic hedging activities, after tax			261
Net loss on the sale of non-wholly-owned nonregulated solar facilities			211
Net loss on the sale of non-wholly-owned nonregulated solar facilities after tax			161
Charge associated with revision in estimated recovery of spent nuclear fuel costs associated with the decommissioning of Kewaunee			44
Charge associated with revision in estimated recovery of spent nuclear fuel costs associated with the decommissioning of Kewaunee, after tax			35
Charge associated with certain nonregulated solar generation facilities				405
Charge associated with certain nonregulated solar generation facilities, net of tax				325
Charge associated with the sale of Fowler Ridge				221
Charge associated with the sale of Fowler Ridge, net of tax				171
Contracted Assets | Operating Segments | Nuclear Decommissioning Trust Funds
Segment Reporting Information [Line Items]
Gain (loss) on investments, after tax			390	237	362
Dominion Energy Virginia | Virginia Legislation
Segment Reporting Information [Line Items]
Benefit from revision of future closure costs					113
Benefit from revision of future closure costs, after tax					84
Dominion Energy Virginia | SCANA
Segment Reporting Information [Line Items]
Charge related to a voluntary retirement program, after-tax					151
Dominion Energy Virginia | Automated Meter Reading Program
Segment Reporting Information [Line Items]
Asset early retirement expense					160
Asset early retirement expense after tax					119
Dominion Energy Virginia | Operating Segments
Segment Reporting Information [Line Items]
Benefit for change in expected CCRO reserve			130
Benefit for change in expected CCRO reserve, after tax			97
Charges associated with budget process related to customer arrears			77
Charges associated with budget process related to customer arrears, after tax			57
Charge associated with storm damage and service restoration			68
Charge associated with storm damage and service restoration, after tax			50
Amortization of regulatory asset			61
Amortization of regulatory asset after tax			45
Loss from unbilled revenue reduction			151
Loss from unbilled revenue reduction, after tax			112
Net charge associated with settlement of the 2021 Triennial Review			125
Net charge associated with settlement of the 2021 Triennial Review, after tax			93
Charge for expected CCRO				130
Charge for expected CCRO, net of tax				97
Charges associated with legislation enacted related to customer arrears				127
Charges associated with legislation enacted related to customer arrears, net of tax				94
Dominion Energy Virginia | Operating Segments | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Payment for contract termination					135
Payment for contract termination after tax					100
Dominion Energy Virginia | Operating Segments | Electric Generation Facilities
Segment Reporting Information [Line Items]
Asset early retirement expense				751	346
Asset early retirement expense after tax				564	257
Dominion Energy Virginia | Operating Segments | Nuclear Decommissioning Trust Funds
Segment Reporting Information [Line Items]
Gain (loss) on investments, after tax			55	27	49
Dominion Energy South Carolina Inc | SCANA
Segment Reporting Information [Line Items]
Charge for refund of amounts from customers, current						$ 137
Charge for refund of amounts from customers, after tax					756
Dominion Energy South Carolina Inc | SCANA | NND Project
Segment Reporting Information [Line Items]
Tax benefit resulting from re-measurement of deferred income taxes as a result of the 2017 Tax Reform Act					194
Income tax regulatory assets		258			258
Dominion Energy South Carolina Inc | Operating Segments
Segment Reporting Information [Line Items]
Litigation settlement expense			70	117	641
Litigation settlement expense, after tax			53	$ 93	480
Charges associated with the settlement of the South Carolina electric base rate case			266
Charges associated with the settlement of the South Carolina electric base rate case, after tax			$ 199
Charge for refund of amounts from customers, current		$ 1,000			1,000
Charge for refund of amounts from customers, after tax					756
Charge related to a voluntary retirement program, after-tax					75
Charge for property, plant and equipment acquired but committed to forgo recovery					114
Charge for property, plant and equipment acquired but committed to forgo recovery, after tax					86
Gas Distribution | SCANA
Segment Reporting Information [Line Items]
Charge related to a voluntary retirement program, after-tax					$ 56

Operating Segments (Schedule of

Operating Segments (Schedule of Segment Reporting Information, by Segment) (Detail) - USD ($) $ in Millions		Nov. 30, 2020	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Operating Revenue				$ 13,964	$ 14,172	$ 14,401
Depreciation, depletion and amortization				2,478	2,332	2,283
Equity in earnings of equity method investees				276	40	8
Interest income				101	107	97
Interest and related charges				1,354	1,377	1,486
Income tax expense		$ 336	$ 173	425	83	209
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest	[1],[2]			641	(1,878)	716
Net income (loss) attributable to Dominion Energy				3,288	(401)	1,358
Investment in equity method affiliates	[3]		2,932	2,932	2,934
Capital expenditures				6,061	6,331	5,321
Total assets			99,590	99,590	95,905
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				13,959	14,197	14,408
Adjustments & Eliminations
Segment Reporting Information [Line Items]
Operating Revenue				60	48	79
Depreciation, depletion and amortization				0	0	0
Equity in earnings of equity method investees				0	0	0
Interest income				(26)	(88)	(136)
Interest and related charges				(26)	(88)	(136)
Income tax expense				0	0	0
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				0	0	0
Net income (loss) attributable to Dominion Energy				0	0	0
Investment in equity method affiliates	[3]		0	0	0
Capital expenditures				0	0	0
Total assets			(5,000)	(5,000)	(4,900)
Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				5	(25)	(7)
Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				(1,004)	(1,039)	(1,160)
Eliminations
Segment Reporting Information [Line Items]
Operating Revenue				(944)	(991)	(1,081)
Dominion Energy Virginia
Segment Reporting Information [Line Items]
Operating Revenue				7,999	7,787	8,157
Dominion Energy Virginia | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				8,012	7,802	8,170
Depreciation, depletion and amortization				1,299	1,247	1,216
Equity in earnings of equity method investees				0	0	0
Interest income				13	13	11
Interest and related charges				537	527	530
Income tax expense				462	496	482
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				0	0	0
Net income (loss) attributable to Dominion Energy				1,919	1,891	1,786
Investment in equity method affiliates	[3]		0	0	0
Capital expenditures				3,762	3,406	3,002
Total assets			50,300	50,300	46,000
Dominion Energy Virginia | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				(13)	(15)	(13)
Gas Distribution
Segment Reporting Information [Line Items]
Operating Revenue				2,665	2,355	2,385
Gas Distribution | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				2,660	2,345	2,367
Depreciation, depletion and amortization				380	344	335
Equity in earnings of equity method investees				0	0	2
Interest income				6	6	4
Interest and related charges				86	76	116
Income tax expense				116	121	114
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				0	0	0
Net income (loss) attributable to Dominion Energy				600	560	487
Investment in equity method affiliates	[3]		106	106	55
Capital expenditures				1,252	1,151	853
Total assets			18,500	18,500	17,100
Gas Distribution | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				5	10	18
Dominion Energy South Carolina
Segment Reporting Information [Line Items]
Operating Revenue				2,975	2,787	2,952
Dominion Energy South Carolina | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				2,968	2,782	2,948
Depreciation, depletion and amortization				486	474	452
Equity in earnings of equity method investees				(3)	(1)	(4)
Interest income				10	12	9
Interest and related charges				206	219	242
Income tax expense				125	107	163
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				0	0	0
Net income (loss) attributable to Dominion Energy				437	419	430
Investment in equity method affiliates	[3]		0	0	0
Capital expenditures				694	700	562
Total assets			16,400	16,400	16,000
Dominion Energy South Carolina | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				7	5	4
Contracted Assets
Segment Reporting Information [Line Items]
Operating Revenue				1,085	1,071	1,156
Contracted Assets | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				1,018	1,020	1,083
Depreciation, depletion and amortization				162	182	180
Equity in earnings of equity method investees				259	35	(1)
Interest income				81	91	97
Interest and related charges				52	75	98
Income tax expense				112	(16)	20
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				0	167	183
Net income (loss) attributable to Dominion Energy				431	402	460
Investment in equity method affiliates	[3]		2,738	2,738	2,784
Capital expenditures				277	649	367
Total assets			12,300	12,300	13,100
Contracted Assets | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				67	51	73
Corporate and Other
Segment Reporting Information [Line Items]
Operating Revenue				184	1,163	832
Corporate and Other | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenue				(759)	200	(239)
Depreciation, depletion and amortization				151	85	100
Equity in earnings of equity method investees				20	6	11
Interest income				17	73	112
Interest and related charges				499	568	636
Income tax expense				(390)	(625)	(570)
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interest				641	(2,045)	533
Net income (loss) attributable to Dominion Energy				(99)	(3,673)	(1,805)
Investment in equity method affiliates	[3]		88	88	95
Capital expenditures				76	425	537
Total assets			$ 7,100	7,100	8,600
Corporate and Other | Intersegment revenue
Segment Reporting Information [Line Items]
Operating Revenue				$ 943	$ 963	$ 1,071
[1]	Includes income tax expense (benefit) of $188 million, $(204) million and $142 million for the years ended December 31, 2021, 2020 and 2019, respectively
[2]	See Note 9 for amounts attributable to related parties
[3]	Excludes liability to Atlantic Coast Pipeline.

Operating Segments - Virginia P

Operating Segments - Virginia Power (Narrative) (Detail) - Operating Segments - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
After- tax net expenses	$ 493	$ 1,200	$ 1,900
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After- tax net expenses	202	863
Benefit for change in expected CCRO reserve	130
Benefit for change in expected CCRO reserve, after tax	97
Charges associated with budget process related to customer arrears	77
Charges associated with budget process related to customer arrears, after tax	57
Charge associated with storm damage and service restoration	68
Charge associated with storm damage and service restoration, after tax	50
Loss from unbilled revenue reduction	151
Loss from unbilled revenue reduction, after tax	112
Net charge associated with settlement of the 2021 Triennial Review	125
Net charge associated with settlement of the 2021 Triennial Review, after tax	93
Amortization of regulatory asset	61
Amortization of regulatory asset after tax	45
Asset early retirement expense		751	346
Asset early retirement expense after tax		559	257
Charge for expected CCRO		130
Charge for expected CCRO, net of tax		97
Charges associated with legislation enacted related to customer arrears		127
Charges associated with legislation enacted related to customer arrears, net of tax		94
Charge related to a voluntary retirement program			198
Charge related to a voluntary retirement program, after-tax			146
Asset planned early retirement expense			160
Asset planned early retirement expense, after tax			119
Payment for contract termination			135
Payment for contract termination, after tax			100
Cancellation abandonment expense			62
Cancellation abandonment expense, after tax			46
Benefit from revision of future closure costs			113
Benefit from revision of future closure costs, after tax			84
Corporate and Other
Segment Reporting Information [Line Items]
After- tax net expenses	99	3,700	1,800
After- tax net expenses for specific items	(97)	3,400	1,500
Corporate and Other | Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After- tax net expenses	202	863	634
After- tax net expenses for specific items	$ 202	$ 915	$ 627

Operating Segments (Schedule _2

Operating Segments (Schedule of Segment Reporting Information, by Segment, Virginia Power) (Detail) - USD ($) $ in Millions		Nov. 30, 2020	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Operating Revenue				$ 13,964	$ 14,172	$ 14,401
Depreciation, depletion and amortization				2,478	2,332	2,283
Interest income				101	107	97
Interest and related charges				1,354	1,377	1,486
Income tax expense		$ 336	$ 173	425	83	209
Net income (loss)				3,288	(401)	1,358
Capital expenditures				6,061	6,331	5,321
Total assets			99,590	99,590	95,905
Dominion Energy Virginia
Segment Reporting Information [Line Items]
Operating Revenue				7,999	7,787	8,157
Corporate and Other
Segment Reporting Information [Line Items]
Operating Revenue				184	1,163	832
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Operating Revenue	[1]			7,470	7,763	8,108
Depreciation, depletion and amortization				1,364	1,252	1,223
Interest income				11	11	11
Interest and related charges	[1]			534	516	524
Income tax expense				397	229	264
Net income (loss)				1,712	1,021	1,149
Capital expenditures				3,756	3,372	2,981
Total assets			47,932	47,932	43,654
Virginia Electric and Power Company | Dominion Energy Virginia
Segment Reporting Information [Line Items]
Operating Revenue				7,976	7,763	8,137
Depreciation, depletion and amortization				1,296	1,245	1,215
Interest income				11	11	11
Interest and related charges				535	524	529
Income tax expense				467	500	481
Net income (loss)				1,914	1,884	1,783
Capital expenditures				3,756	3,372	2,981
Total assets			47,900	47,900	43,700
Virginia Electric and Power Company | Corporate and Other
Segment Reporting Information [Line Items]
Operating Revenue				(506)	0	(29)
Depreciation, depletion and amortization				68	7	8
Interest income				0	0	0
Interest and related charges				(1)	(8)	(5)
Income tax expense				(70)	(271)	(217)
Net income (loss)				(202)	(863)	(634)
Capital expenditures				0	0	$ 0
Total assets			$ 0	$ 0	$ 0
[1]	See Note 25 for amounts attributable to affiliates.