Southern California Gas Company PFD 6% (SOCGM) 10-K 25 Feb 22 2021 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Dec. 31, 2021	Feb. 18, 2022	Jun. 30, 2021
Document And Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA ENERGY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 41,700,000,000
Entity Common Stock, Shares Outstanding		315,653,893
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Sempra Energy proxy statement to be filed for its May 2022 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K. Portions of the Southern California Gas Company information statement to be filed for its June 2022 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K.
Entity Central Index Key	0001032208
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
San Diego Gas and Electric Company [Member]
Document And Entity Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8326 Century Park Court
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92123
City Area Code	(619)
Local Phone Number	696-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			0
Entity Central Index Key	0000086521
SoCalGas
Document And Entity Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West Fifth Street
Entity Address, City or Town	Los Angeles
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90013
City Area Code	(213)
Local Phone Number	244-1200
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 0
Entity Central Index Key	0000092108
Common Stock
Document And Entity Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
5.75% Junior Subordinated Notes Due 2079 [Member]
Document And Entity Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE
Preferred stock | SoCalGas
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, $25 par value
Preferred Stock Series A [Member] | SoCalGas
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, Series A, $25 par value

AUDIT INFORMATION

AUDIT INFORMATION	12 Months Ended
	Dec. 31, 2021
Audit Information [Abstract]
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	San Diego, California
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues
Natural Gas	$ 6,333	$ 5,411	$ 5,185
Electric	4,658	4,614	4,263
Energy-related businesses	1,866	1,345	1,381
Total revenues	12,857	11,370	10,829
EXPENSES AND OTHER INCOME
Operation and maintenance	(4,338)	(3,940)	(3,466)
Aliso canyon litigation and regulatory matters	(1,593)	(307)	0
Depreciation and amortization	(1,855)	(1,666)	(1,569)
Franchise fees and other taxes	(596)	(543)	(496)
Impairment losses	(3)	(1)	(43)
Gain (loss) on sale of assets	36	(3)	63
Other income (expense), net	58	(48)	77
Interest income	69	96	87
Interest expense	(1,198)	(1,081)	(1,077)
Income from continuing operations before income taxes and equity earnings	219	1,489	1,734
Income tax expense	(99)	(249)	(315)
Equity earnings	1,343	1,015	580
Income from continuing operations, net of tax	1,463	2,255	1,999
Income from discontinued operations, net of income tax	0	1,850	363
Net income	1,463	4,105	2,362
Earnings attributable to noncontrolling interest	(145)	(172)	(164)
Preferred dividends	(63)	(168)	(142)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings attributable to common shares	$ 1,254	$ 3,764	$ 2,055
Basic EPS:
Earnings from continuing operations attributable to common shares	$ 4.03	$ 6.61	$ 6.22
Earning from discontinued operations	0	6.32	1.18
Earnings	$ 4.03	$ 12.93	$ 7.40
Weighted-average common shares outstanding for basic EPS (in shares)	311,755	291,077	277,904
Diluted EPS:
Earnings from continuing operations - Diluted EPS (in dollars per share)	$ 4.01	$ 6.58	$ 6.13
Earnings from discontinued operations	0	6.30	1.16
Earnings	$ 4.01	$ 12.88	$ 7.29
Weighted Average Common Shares Outstanding	313,036	292,252	282,033
Cost of natural gas
EXPENSES AND OTHER INCOME
Operating expenses	$ (1,597)	$ (925)	$ (1,139)
Cost of electric fuel and purchased power
EXPENSES AND OTHER INCOME
Operating expenses	(1,010)	(1,187)	(1,188)
Energy-related businesses cost of sales
EXPENSES AND OTHER INCOME
Operating expenses	$ (611)	$ (276)	$ (344)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ 1,463	$ 4,105	$ 2,362
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	422	(140)
Preferred dividends of subsidiary	(1)	(1)	(1)
Pretax amount
Net income	1,417	5,368	2,585
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Comprehensive income	1,630	5,780	2,406
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	1,629	5,779	2,405
Income tax (expense) benefit
Net income	(99)	(1,435)	(387)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Comprehensive income	(152)	(1,401)	(341)
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	(152)	(1,401)	(341)
Net-of-tax amount
Net income	1,318	3,933	2,198
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Comprehensive income	1,478	4,379	2,065
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	1,477	4,378	2,064
Noncontrolling interests (after tax)
Net income	145	172	164
Other comprehensive income (loss):
Foreign currency translation adjustments	(3)	(12)	3
Financial instruments	14	(12)	(10)
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	11	(24)	(7)
Comprehensive income	156	148	157
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	156	148	157
Total
Net income	1,463	4,105	2,362
Other comprehensive income (loss):
Foreign currency translation adjustments	(9)	535	(40)
Financial instruments	158	(125)	(118)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	171	422	(140)
Comprehensive income	1,634	4,527	2,222
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	$ 1,633	$ 4,526	$ 2,221

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 559	$ 960	$ 108
Restricted cash	19	22	31
Accounts receivable – trade, net	2,071	1,578	1,261
Accounts receivable – other, net	398	403	455
Due from unconsolidated affiliates	23	20	32
Income taxes receivable	79	113	112
Inventories	389	308	277
Prepaid expenses	260	215	161
Regulatory assets	271	190	222
Greenhouse gas allowances	97	553	72
Assets held for sale in discontinued operations	0	0	445
Other current assets	209	149	163
Total current assets	4,375	4,511	3,339
Other assets:
Restricted cash	3	3	3
Due from unconsolidated affiliates	637	780	742
Regulatory assets	2,011	1,822	1,930
Insurance receivable for Aliso Canyon costs	360	445	339
Greenhouse gas allowances	422	101	470
Nuclear decommissioning trusts	1,012	1,019	1,082
Dedicated assets in support of certain benefit plans	567	512	488
Deferred income taxes	151	136	155
Right-of-use assets – operating leases	594	543	591
Investment in Oncor Holdings	12,947	12,440	11,519
Other investments	1,525	1,388	2,103
Goodwill	1,602	1,602	1,602
Other intangible assets	370	202	213
Wildfire fund	331	363	392
Assets held for sale in discontinued operations	0	0	3,513
Other long-term assets	1,244	753	732
Total other assets	23,776	22,109	25,874
Property, plant and equipment:
Property, plant and equipment	58,940	53,928	49,329
Less accumulated depreciation and amortization	(15,046)	(13,925)	(12,877)
Property, plant and equipment, net	43,894	40,003	36,452
Total assets	72,045	66,623	65,665
Current liabilities:
Short-term debt	3,471	885	3,505
Accounts payable – trade	1,671	1,359	1,234
Accounts payable – other	178	154	179
Due to unconsolidated affiliates	0	45	5
Dividends and interest payable	563	551	515
Accrued compensation and benefits	479	446	476
Regulatory liabilities	359	140	319
Current portion of long-term debt and finance leases	106	1,540	1,526
Reserve for Aliso Canyon costs	1,980	150	9
Greenhouse gas obligations	97	553	72
Liabilities held for sale in discontinued operations	0	0	444
Other current liabilities	1,131	1,016	866
Total current liabilities	10,035	6,839	9,150
Long-term debt and finance leases	21,068	21,781	20,785
Deferred credits and other liabilities:
Due to unconsolidated affiliates	287	234	195
Regulatory liabilities	3,402	3,372	3,741
Reserve for Aliso Canyon costs	3	301	7
Greenhouse gas obligations	225	0	301
Pension and other postretirement benefit plan obligations, net of plan assets	687	1,059	1,067
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	3,375	3,113	2,923
Liabilities held for sale in discontinued operations	0	0	1,052
Deferred credits and other	2,067	2,119	2,062
Total deferred credits and other liabilities	13,523	13,069	13,925
Commitments and contingencies (Note 16)
Equity:
Common stock	11,862	7,053	7,480
Retained earnings	13,548	13,673	11,130
Accumulated other comprehensive income (loss)	(318)	(500)	(939)
Total shareholders’ equity	25,981	23,373	19,929
Preferred stock of subsidiary	20	20	20
Other noncontrolling interests	1,418	1,541	1,856
Total equity	27,419	24,934	21,805
Total liabilities and shareholders’ equity	72,045	66,623	65,665
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925	273,769,513
Convertible Preferred Stock Series A
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		17,250,000	17,250,000
Convertible Preferred Stock Series B
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		5,750,000	5,750,000
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,463	$ 4,105	$ 2,362
Less: Income from discontinued operations, net of income tax	0	(1,850)	(363)
Income from continuing operations, net of income tax	1,463	2,255	1,999
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,855	1,666	1,569
Deferred income taxes and investment tax credits	(78)	159	189
Impairment losses	3	1	43
(Gain) loss on sale of assets	(36)	3	(63)
Equity earnings	1,343	1,015	580
Foreign currency transaction losses (gains), net	18	25	(21)
Share-based compensation expense	63	71	75
Fixed-price contracts and other derivatives	206	(7)	(11)
Other	167	139	58
Net change in other working capital components:
Accounts receivable	(599)	(328)	(97)
Due to/from unconsolidated affiliates, net	(1)	12	1
Income taxes receivable/payable, net	(38)	(94)	(166)
Inventories	(87)	(35)	(22)
Other current assets	(220)	38	(88)
Accounts payable	263	74	17
Regulatory balancing accounts, net	249	(231)	13
Reserve for Aliso Canyon costs	1,532	141	(144)
Other current liabilities	(105)	(127)	(99)
Intercompany activities with discontinued operations, net	0	0	378
Insurance receivable for Aliso Canyon costs	85	(106)	122
Distributions from investments	941	651	247
Wildfire fund, current and noncurrent	0	0	(323)
Reserve for Aliso Canyon costs, noncurrent	0	294	0
Changes in other noncurrent assets and liabilities, net	(496)	56	(399)
Net cash provided by continuing operations	3,842	3,642	2,698
Net cash (used in) provided by discontinued operations	0	(1,051)	390
Net cash provided by operating activities	3,842	2,591	3,088
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,015)	(4,676)	(3,708)
Expenditures for investments and acquisitions	(633)	(652)	(1,797)
Proceeds from sale of assets	38	19	899
Distributions from investments	366	761	9
Purchases of nuclear decommissioning trust assets	(961)	(1,439)	(914)
Proceeds from sales of nuclear decommissioning trust assets	961	1,439	914
Advances to unconsolidated affiliates	(8)	(92)	(16)
Repayments of advances to unconsolidated affiliates	38	7	3
Disbursement for note receivable	(305)	0	0
Intercompany activities with discontinued operations, net	0	0	8
Other	11	15	21
Net cash used in continuing operations	(5,508)	(4,618)	(4,581)
Net cash provided by (used in) discontinued operations	0	5,171	(12)
Net cash (used in) provided by investing activities	(5,508)	553	(4,593)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,331)	(1,174)	(993)
Preferred dividends paid	(99)	(157)	(142)
Proceeds from Issuance of Preferred Stock and Preference Stock	0	891	0
Issuances of common stock, net	5	11	1,830
Repurchases of common stock	(339)	(566)	(26)
Issuances of debt (maturities greater than 90 days)	3,773	6,051	4,296
Payments on debt (maturities greater than 90 days) and finance leases	(5,489)	(5,864)	(3,667)
Increase (decrease) in short-term debt, net	1,913	(1,759)	656
Advances from unconsolidated affiliates	40	64	155
Purchases of noncontrolling interests	(224)	(248)	(30)
Proceeds from sales of noncontrolling interests, net	3,206	26	5
Proceeds from (Payments to) Noncontrolling Interests	4	1	98
Intercompany activities with discontinued operations, net	0	0	(266)
Other	(199)	(50)	(49)
Net cash provided by continuing operations	1,260	(2,774)	1,867
Net cash (used in) provided by discontinued operations	0	401	(392)
Net cash provided by financing activities	1,260	(2,373)	1,475
Effect of exchange rate changes in continuing operations	2	0	0
Effect of exchange rate changes in discontinued operations	0	(3)	1
Effect of exchange rate changes on cash, cash equivalents and restricted cash	2	(3)	1
Increase (decrease) in cash and cash equivalents	(404)	768	(29)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	985	217	246
Cash, cash equivalents and restricted cash, including discontinued operations, December 31	581	985	217
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	1,163	1,046	1,051
Income tax payments (refunds), net	230	1,385	360
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued commercial paper proceeds	0	0	67
Accrued interest receivable from unconsolidated affiliate	0	0	55
Contribution to Cameron LNG JV	0	50	0
Distribution from Cameron LNG JV	0	50	0
Increase in Cameron LNG JV investment for guarantee	22	0	0
Repayment of advances from unconsolidated affiliate in lieu of distribution	45	0	0
Accrued capital expenditures	591	535	515
Increase in finance lease obligations for investment in PP&E	43	77	38
Derecognized PP&E for net investment in sales-type lease	44	0	0
Increase in ARO for investment in PP&E	153	142	36
Equitization of long-term debt for deficit held by NCI	0	22	0
Accrued purchase price adjustment for sale of NCI	13	0	0
Issuance of common stock in exchange for NCI and related AOCI	1,373	0	0
Common dividends issued in stock	0	22	55
Conversion of mandatory convertible preferred stock	2,258	0	0
Common Stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	349	301	283
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	$ 11	$ 47	$ 36

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Preferred stock	Preferred stockCumulative Effect, Period of Adoption, Adjusted Balance	Common stock	Common stockCumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings	Retained earningsCumulative Effect, Period of Adoption, Adjustment	Retained earningsCumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjusted Balance	Sempra Energy shareholders' equity	Sempra Energy shareholders' equityCumulative Effect, Period of Adoption, Adjustment	Sempra Energy shareholders' equityCumulative Effect, Period of Adoption, Adjusted Balance	Non- controlling interests	Non- controlling interestsCumulative Effect, Period of Adoption, Adjustment	Non- controlling interestsCumulative Effect, Period of Adoption, Adjusted Balance	Preferred Class A	Preferred Class APreferred stock	Preferred Class ACommon stock	Preferred Class ARetained earnings	Preferred Class ASempra Energy shareholders' equity	Preferred Class B	Preferred Class BPreferred stock	Preferred Class BCommon stock	Preferred Class BRetained earnings	Preferred Class BSempra Energy shareholders' equity	Series C Preferred Stock	Series C Preferred StockPreferred stock	Series C Preferred StockRetained earnings	Series C Preferred StockSempra Energy shareholders' equity
Beginning Balance at Dec. 31, 2018	$ 19,248		$ 19,263	$ 2,258	$ 2,258	$ 5,540	$ 5,540	$ 10,104		$ 10,161	$ (764)		$ (806)	$ 17,138		$ 17,153	$ 2,110		$ 2,110
Beginning Balance (Accounting Standards Update 2016-02) at Dec. 31, 2018		$ 17							$ 17						$ 17
Beginning Balance (Accounting Standards Update 2018-02) at Dec. 31, 2018		(2)							40			$ (42)			(2)
Accounting Standards Update [Extensible List] | Accounting Standards Update 2016-13 [Member]	Accounting Standards Update 2016-13 [Member]
Net income	$ 2,362							2,198						2,198			164
Other comprehensive income	(140)										(133)			(133)			(7)
Share-based compensation expense	75					75								75
Preferred stock dividends declared																				$ (103)			$ (103)	$ (103)	$ (39)			$ (39)	$ (39)
Common stock dividends declared	(1,086)							(1,086)						(1,086)
Preferred dividends of subsidiary	(1)							(1)						(1)
Issuances of stock	1,885					1,885								1,885
Repurchases of common stock	(26)					(26)								(26)
Contributions	175																175
Distributions	(98)					5								5			(103)
Purchases	(30)					(3)								(3)			(27)
Sale	5					4								4			1
Acquisition	3																3
Deconsolidations	(440)																(440)
Ending balance at Dec. 31, 2019	21,805		$ 21,796	2,258	$ 2,258	7,480	$ 7,480	11,130		$ 11,123	(939)		$ (939)	19,929		$ 19,922	1,876		$ 1,874
Ending balance (Accounting Standards Update 2016-13 [Member]) at Dec. 31, 2019		$ (9)							$ (7)						$ (7)			$ (2)
Net income	4,105							3,933						3,933			172
Other comprehensive income	422										446			446			(24)
Share-based compensation expense	71					71								71
Preferred stock dividends declared																				(104)			$ (104)	(104)	(39)			(39)	(39)	$ (25)		$ (25)	$ (25)
Common stock dividends declared	(1,214)							(1,214)						(1,214)
Preferred dividends of subsidiary	(1)							(1)						(1)
Issuances of stock	33					33								33																889	$ 889		889
Repurchases of common stock	(566)					(566)								(566)
Contributions	1																1
Distributions	(1)																(1)
Purchases	(248)					34					(7)			27			(275)
Sale	28					1								1			27
Acquisition	1																1
Equitization of long-term debt for deficit held by NCI	22																22
Deconsolidations	(236)																(236)
Ending balance at Dec. 31, 2020	24,934			3,147		7,053		13,673			(500)			23,373			1,561
Net income	1,463							1,318						1,318			145
Other comprehensive income	171										160			160			11
Share-based compensation expense	63					63								63
Preferred stock dividends declared																									(19)			$ (19)	(19)	$ (44)		$ (44)	$ (44)
Common stock dividends declared	(1,379)							(1,379)						(1,379)
Preferred dividends of subsidiary	(1)							(1)						(1)
Conversion of stock																				$ 0	$ (1,693)	$ 1,693		$ 0	$ 0	$ (565)	$ 565		$ 0
Issuances of stock	5					5								5
Repurchases of common stock	(339)					(339)								(339)
Contributions	4																4
Purchases	(152)					1,459					(44)			1,415			(1,567)
Sale	2,712					1,363					66			1,429			1,283
Deconsolidations	1																1
Ending balance at Dec. 31, 2021	$ 27,419			$ 889		$ 11,862		$ 13,548			$ (318)			$ 25,981			$ 1,438

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Common stock dividends declared (USD per share)	$ 4.18	$ 3.87
Preferred Class A
Preferred stock, dividends declared per share (USD per share)	6	6
Preferred Class B
Preferred stock, dividends declared per share (USD per share)	6.75	$ 6.75
Series C Preferred Stock
Preferred stock, dividends declared per share (USD per share)	$ 27.90

CONSOLIDATED STATEMENTS OF OP_2

CONSOLIDATED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues
Electric	$ 4,658	$ 4,614	$ 4,263
Natural Gas	6,333	5,411	5,185
Operating expenses
Other income, net	58	(48)	77
Interest income	69	96	87
Interest expense	(1,198)	(1,081)	(1,077)
Income (loss) before income taxes	219	1,489	1,734
Income tax expense	(99)	(249)	(315)
Net income	1,463	4,105	2,362
Earnings attributable to noncontrolling interest	(145)	(172)	(164)
Earnings attributable to common shares	1,254	3,764	2,055
San Diego Gas and Electric Company [Member]
Revenues
Electric	4,666	4,619	4,267
Natural Gas	838	694	658
Total operating revenues	5,504	5,313	4,925
Operating expenses
Cost of electric fuel and purchased power	1,069	1,191	1,194
Cost of natural gas	242	162	176
Operation and maintenance	1,587	1,455	1,181
Depreciation and amortization	889	801	760
Franchise fees and other taxes	350	331	301
Total operating expenses	4,137	3,940	3,612
Operating Income	1,367	1,373	1,313
Other income, net	64	52	39
Interest income	1	2	4
Interest expense	(412)	(413)	(411)
Income (loss) before income taxes	1,020	1,014	945
Income tax expense	(201)	(190)	(171)
Net income	819	824	774
Earnings attributable to noncontrolling interest	0	0	(7)
Earnings attributable to common shares	$ 819	$ 824	$ 767

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ 1,463	$ 4,105	$ 2,362
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	422	(140)
Pretax amount
Net income	1,417	5,368	2,585
Other comprehensive income (loss):
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Total comprehensive income, after preferred dividends of subsidiaries	1,629	5,779	2,405
Income tax (expense) benefit
Net income	(99)	(1,435)	(387)
Other comprehensive income (loss):
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Total comprehensive income, after preferred dividends of subsidiaries	(152)	(1,401)	(341)
Net-of-tax amount
Net income	1,318	3,933	2,198
Other comprehensive income (loss):
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Total comprehensive income, after preferred dividends of subsidiaries	1,477	4,378	2,064
Noncontrolling interests (after tax)
Net income	145	172	164
Other comprehensive income (loss):
Financial instruments	14	(12)	(10)
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	11	(24)	(7)
Total comprehensive income, after preferred dividends of subsidiaries	156	148	157
Total
Net income	1,463	4,105	2,362
Other comprehensive income (loss):
Financial instruments	158	(125)	(118)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	171	422	(140)
Total comprehensive income, after preferred dividends of subsidiaries	1,633	4,526	2,221
San Diego Gas and Electric Company [Member]
Net income	819	824	774
Other comprehensive income (loss):
Total other comprehensive (loss) income		6	(2)
San Diego Gas and Electric Company [Member] | Pretax amount
Net income	1,020	1,014	938
Other comprehensive income (loss):
Financial instruments			0
Pension and other postretirement benefits		8	(6)
Total other comprehensive (loss) income		8	(6)
Total comprehensive income, after preferred dividends of subsidiaries	1,020	1,022	932
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit
Net income	(201)	(190)	(171)
Other comprehensive income (loss):
Financial instruments			0
Pension and other postretirement benefits		(2)	2
Total other comprehensive (loss) income		(2)	2
Total comprehensive income, after preferred dividends of subsidiaries	(201)	(192)	(169)
San Diego Gas and Electric Company [Member] | Net-of-tax amount
Net income	819	824	767
Other comprehensive income (loss):
Financial instruments			0
Pension and other postretirement benefits		6	(4)
Total other comprehensive (loss) income		6	(4)
Total comprehensive income, after preferred dividends of subsidiaries	819	830	763
San Diego Gas and Electric Company [Member] | Noncontrolling interests (after tax)
Net income	0	0	7
Other comprehensive income (loss):
Financial instruments			2
Pension and other postretirement benefits		0	0
Total other comprehensive (loss) income		0	2
Total comprehensive income, after preferred dividends of subsidiaries	0	0	9
San Diego Gas and Electric Company [Member] | Total
Net income	819	824	774
Other comprehensive income (loss):
Financial instruments			2
Pension and other postretirement benefits		6	(4)
Total other comprehensive (loss) income		6	(2)
Total comprehensive income, after preferred dividends of subsidiaries	$ 819	$ 830	$ 772

CONSOLIDATED BALANCE SHEETS - S

CONSOLIDATED BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 559	$ 960	$ 108
Accounts receivable – trade, net	2,071	1,578	1,261
Accounts receivable – other, net	398	403	455
Income taxes receivable, net	79	113	112
Inventories	389	308	277
Prepaid expenses	260	215	161
Regulatory assets	271	190	222
Greenhouse gas allowances	97	553	72
Other current assets	209	149	163
Total current assets	4,375	4,511	3,339
Other assets:
Regulatory assets	2,011	1,822	1,930
Greenhouse gas allowances	422	101	470
Nuclear decommissioning trusts	1,012	1,019	1,082
Right-of-use assets – operating leases	594	543	591
Wildfire fund	331	363	392
Other long-term assets	1,244	753	732
Total other assets	23,776	22,109	25,874
Property, plant and equipment:
Property, plant and equipment	58,940	53,928	49,329
Less accumulated depreciation and amortization	(15,046)	(13,925)	(12,877)
Property, plant and equipment, net	43,894	40,003	36,452
ASSETS	72,045	66,623	65,665
Current liabilities:
Short-term debt	3,471	885	3,505
Accounts payable	1,671	1,359	1,234
Due to unconsolidated affiliates	0	45	5
Accrued compensation and benefits	479	446	476
Regulatory liabilities	359	140	319
Current portion of long-term debt and finance leases	106	1,540	1,526
Greenhouse gas obligations	97	553	72
Other current liabilities	1,131	1,016	866
Total current liabilities	10,035	6,839	9,150
Long-term debt and finance leases	21,068	21,781	20,785
Deferred credits and other liabilities:
Regulatory liabilities	3,402	3,372	3,741
Greenhouse gas obligations	225	0	301
Pension obligation, net of plan assets	687	1,059	1,067
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	3,375	3,113	2,923
Deferred credits and other	2,067	2,119	2,062
Total deferred credits and other liabilities	13,523	13,069	13,925
Commitments and contingencies (Note 16)
Equity:
Common stock	11,862	7,053	7,480
Retained earnings	13,548	13,673	11,130
Accumulated other comprehensive income (loss)	(318)	(500)	(939)
Total shareholders’ equity	25,981	23,373	19,929
Total liabilities and shareholders’ equity	72,045	66,623	65,665
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	25	262	10
Accounts receivable – trade, net	715	573	398
Accounts receivable – other, net	78	143	119
Income taxes receivable, net	9	0	128
Inventories	123	104	94
Prepaid expenses	174	153	120
Regulatory assets	231	174	209
Greenhouse gas allowances	13	113	13
Other current assets	63	78	67
Total current assets	1,431	1,600	1,158
Other assets:
Regulatory assets	786	534	440
Greenhouse gas allowances	111	83	189
Nuclear decommissioning trusts	1,012	1,019	1,082
Right-of-use assets – operating leases	185	102	130
Wildfire fund	331	363	392
Other long-term assets	154	189	202
Total other assets	2,579	2,290	2,435
Property, plant and equipment:
Property, plant and equipment	26,456	24,436	22,504
Less accumulated depreciation and amortization	(6,408)	(6,015)	(5,537)
Property, plant and equipment, net	20,048	18,421	16,967
ASSETS	24,058	22,311	20,560
Current liabilities:
Short-term debt	776	0	80
Accounts payable	588	553	496
Due to unconsolidated affiliates	97	64	53
Accrued compensation and benefits	148	135	138
Regulatory liabilities	14	61	76
Current portion of long-term debt and finance leases	49	611	56
Customer deposits	30	56	74
Greenhouse gas obligations	13	113	13
Asset retirement obligations	86	117	95
Other current liabilities	310	301	229
Total current liabilities	2,111	2,011	1,310
Long-term debt and finance leases	7,581	6,866	6,306
Deferred credits and other liabilities:
Regulatory liabilities	2,302	2,195	2,319
Greenhouse gas obligations	31	0	62
Pension obligation, net of plan assets	25	92	153
Deferred income taxes	2,275	2,019	1,848
Asset retirement obligations	804	759	771
Deferred credits and other	680	639	691
Total deferred credits and other liabilities	6,117	5,704	5,844
Commitments and contingencies (Note 16)
Equity:
Preferred stock	0	0	0
Common stock	1,660	1,660	1,660
Retained earnings	6,599	6,080	5,456
Accumulated other comprehensive income (loss)	(10)	(10)	(16)
Total shareholders’ equity	8,249	7,730	7,100
Total liabilities and shareholders’ equity	24,058	22,311	20,560
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

CONSOLIDATED BALANCE SHEETS -_2

CONSOLIDATED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925
San Diego Gas and Electric Company [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	117,000,000	117,000,000	117,000,000

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,463	$ 4,105	$ 2,362
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes and investment tax credits	(78)	159	189
Other	167	139	58
Net change in other working capital components:
Accounts receivable	(599)	(328)	(97)
Due to/from unconsolidated affiliates, net	(1)	12	1
Income taxes receivable/payable, net	(38)	(94)	(166)
Inventories	(87)	(35)	(22)
Other current assets	(220)	38	(88)
Accounts payable	263	74	17
Regulatory balancing accounts, net	249	(231)	13
Other current liabilities	(105)	(127)	(99)
Wildfire fund, current and noncurrent	0	0	(323)
Changes in other noncurrent assets and liabilities, net	(496)	56	(399)
Net cash provided by operating activities	3,842	2,591	3,088
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,015)	(4,676)	(3,708)
Purchases of nuclear decommissioning trust assets	(961)	(1,439)	(914)
Proceeds from sales of nuclear decommissioning trust assets	961	1,439	914
Other	11	15	21
Net cash (used in) provided by investing activities	(5,508)	553	(4,593)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,331)	(1,174)	(993)
Issuances of debt (maturities greater than 90 days)	3,773	6,051	4,296
Payments on debt (maturities greater than 90 days) and finance leases	(5,489)	(5,864)	(3,667)
Increase (decrease) in short-term debt, net	1,913	(1,759)	656
Proceeds from sales of noncontrolling interests, net	3,206	26	5
Net cash provided by financing activities	1,260	(2,373)	1,475
Increase (decrease) in cash and cash equivalents	(404)	768	(29)
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	1,163	1,046	1,051
Income tax payments (refunds), net	230	1,385	360
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	591	535	515
Increase in finance lease obligations for investment in PP&E	43	77	38
Increase in ARO for investment in PP&E	153	142	36
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	819	824	774
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	889	801	760
Deferred income taxes and investment tax credits	153	35	105
Other	(14)	27	13
Net change in other working capital components:
Accounts receivable	(105)	(134)	(15)
Due to/from unconsolidated affiliates, net	33	11	(8)
Income taxes receivable/payable, net	(20)	129	(126)
Inventories	(19)	(10)	4
Other current assets	0	4	(19)
Accounts payable	7	31	32
Regulatory balancing accounts, net	(57)	(71)	(101)
Other current liabilities	(92)	(100)	4
Wildfire fund, current and noncurrent	0	0	(323)
Changes in other noncurrent assets and liabilities, net	(218)	(158)	(10)
Net cash provided by operating activities	1,376	1,389	1,090
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(2,220)	(1,942)	(1,522)
Purchases of nuclear decommissioning trust assets	(961)	(1,439)	(914)
Proceeds from sales of nuclear decommissioning trust assets	961	1,439	914
Other	7	8	0
Net cash (used in) provided by investing activities	(2,213)	(1,934)	(1,522)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(300)	(200)	0
Equity contribution from Sempra Energy	0	0	322
Issuances of debt (maturities greater than 90 days)	1,120	1,598	400
Payments on debt (maturities greater than 90 days) and finance leases	(613)	(510)	(274)
Increase (decrease) in short-term debt, net	401	(80)	(211)
Proceeds from sales of noncontrolling interests, net	0	0	172
Debt issuance costs	(8)	(11)	(4)
Net cash provided by financing activities	600	797	405
Increase (decrease) in cash and cash equivalents	(237)	252	(27)
Cash and cash equivalents, January 1	262	10	37
Cash and cash equivalents, December 31	25	262	10
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	402	404	405
Income tax payments (refunds), net	67	25	191
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	228	199	174
Increase in finance lease obligations for investment in PP&E	24	30	16
Increase in ARO for investment in PP&E	$ 14	$ 31	$ (1)

CONSOLIDATED STATEMENTS OF CH_3

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SDG&E - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Common stock	Common stockCumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings	Retained earningsCumulative Effect, Period of Adoption, Adjustment	Retained earningsCumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjusted Balance	Sempra Energy shareholders' equity	Sempra Energy shareholders' equityCumulative Effect, Period of Adoption, Adjustment	Sempra Energy shareholders' equityCumulative Effect, Period of Adoption, Adjusted Balance	Non- controlling interests	Non- controlling interestsCumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]	San Diego Gas and Electric Company [Member]Cumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Common stock	San Diego Gas and Electric Company [Member]Common stockCumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Retained earnings	San Diego Gas and Electric Company [Member]Retained earningsCumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Retained earningsCumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss)	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Sempra Energy shareholders' equity	San Diego Gas and Electric Company [Member]Sempra Energy shareholders' equityCumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Non- controlling interests	San Diego Gas and Electric Company [Member]Non- controlling interestsCumulative Effect, Period of Adoption, Adjusted Balance
Beginning Balance at Dec. 31, 2018	$ 19,248		$ 19,263	$ 5,540	$ 5,540	$ 10,104		$ 10,161	$ (764)		$ (806)	$ 17,138		$ 17,153	$ 2,110	$ 2,110	$ 6,115		$ 6,115	$ 1,338	$ 1,338	$ 4,687		$ 4,689	$ (10)		$ (12)	$ 6,015	$ 6,015	$ 100	$ 100
Beginning Balance (Accounting Standards Update 2018-02) at Dec. 31, 2018		$ (2)					$ 40			$ (42)			$ (2)					$ 0					$ 2			$ (2)
Net income	2,362					2,198						2,198			164		774					767						767		7
Other comprehensive income	(140)								(133)			(133)			(7)		(2)								(4)			(4)		2
Equity contribution from Sempra Energy																	322			322								322
Contributions	175														175		175													175
Distributions	(98)			5								5			(103)		(3)													(3)
Deconsolidations	(440)														(440)		(281)													(281)
Common stock dividends declared	(1,086)					(1,086)						(1,086)
Ending balance at Dec. 31, 2019	21,805		$ 21,796	7,480	$ 7,480	11,130		$ 11,123	(939)		$ (939)	19,929		$ 19,922	1,876	$ 1,874	7,100			1,660		5,456			(16)			7,100		0
Net income	4,105					3,933						3,933			172		824					824						824
Other comprehensive income	422								446			446			(24)		6								6			6
Contributions	1														1
Distributions	(1)														(1)
Deconsolidations	(236)														(236)
Common stock dividends declared	(1,214)					(1,214)						(1,214)					(200)					(200)						(200)
Ending balance at Dec. 31, 2020	24,934			7,053		13,673			(500)			23,373			1,561		7,730			1,660		6,080			(10)			7,730
Net income	1,463					1,318						1,318			145		819					819						819
Other comprehensive income	171								160			160			11
Contributions	4														4
Deconsolidations	1														1
Common stock dividends declared	(1,379)					(1,379)						(1,379)					(300)					(300)						(300)
Ending balance at Dec. 31, 2021	$ 27,419			$ 11,862		$ 13,548			$ (318)			$ 25,981			$ 1,438		$ 8,249			$ 1,660		$ 6,599			$ (10)			$ 8,249		$ 0

CONSOLIDATED STATEMENTS OF CH_4

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SDG&E (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Common stock dividends declared (USD per share)	$ 4.40	$ 4.18
San Diego Gas and Electric Company [Member]
Common stock dividends declared (USD per share)	$ 2.57	$ 1.72

CONSOLIDATED STATEMENTS OF OP_3

CONSOLIDATED STATEMENTS OF OPERATIONS - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating expenses
Aliso canyon litigation and regulatory matters	$ 1,593	$ 307	$ 0
Impairment losses	3	1	43
Other income (expense), net	58	(48)	77
Interest income	69	96	87
Interest expense	(1,198)	(1,081)	(1,077)
Income (loss) before income taxes	219	1,489	1,734
Income tax benefit (expense)	(99)	(249)	(315)
Net income	1,463	4,105	2,362
Preferred dividends	(63)	(168)	(142)
Earnings attributable to common shares	1,254	3,764	2,055
SoCalGas
Operating revenue	5,515	4,748	4,525
Operating expenses
Cost of natural gas	1,369	783	977
Operation and maintenance	2,180	2,029	1,780
Aliso canyon litigation and regulatory matters	1,593	307	0
Depreciation and amortization	716	654	602
Franchise fees and other taxes	223	190	173
Impairment losses	0	0	37
Total operating expenses	6,081	3,963	3,569
Operating (loss) income	(566)	785	956
Other income (expense), net	(14)	(28)	(55)
Interest income	1	2	2
Interest expense	(157)	(158)	(141)
Income (loss) before income taxes	(736)	601	762
Income tax benefit (expense)	310	(96)	(120)
Net income	(426)	505	642
Preferred dividends	(1)	(1)	(1)
Earnings attributable to common shares	$ (427)	$ 504	$ 641

CONSOLIDATED STATEMENTS OF CO_3

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net (loss) income	$ 1,463	$ 4,105	$ 2,362
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	422	(140)
Pretax amount
Net (loss) income	1,417	5,368	2,585
Other comprehensive income (loss):
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Comprehensive income	1,630	5,780	2,406
Income tax (expense) benefit
Net (loss) income	(99)	(1,435)	(387)
Other comprehensive income (loss):
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Comprehensive income	(152)	(1,401)	(341)
Net-of-tax amount
Net (loss) income	1,318	3,933	2,198
Other comprehensive income (loss):
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Comprehensive income	1,478	4,379	2,065
SoCalGas
Net (loss) income	(426)	505	642
Other comprehensive income (loss):
Total other comprehensive (loss) income		(8)	1
SoCalGas | Pretax amount
Net (loss) income	(736)	601	762
Other comprehensive income (loss):
Financial instruments			1
Pension and other postretirement benefits		(12)	1
Total other comprehensive (loss) income		(12)	2
Comprehensive income	(736)	589	764
SoCalGas | Income tax (expense) benefit
Net (loss) income	310	(96)	(120)
Other comprehensive income (loss):
Financial instruments			0
Pension and other postretirement benefits		4	(1)
Total other comprehensive (loss) income		4	(1)
Comprehensive income	310	(92)	(121)
SoCalGas | Net-of-tax amount
Net (loss) income	(426)	505	642
Other comprehensive income (loss):
Financial instruments			1
Pension and other postretirement benefits		(8)	0
Total other comprehensive (loss) income		(8)	1
Comprehensive income	$ (426)	$ 497	$ 643

CONSOLIDATED BALANCE SHEETS -_3

CONSOLIDATED BALANCE SHEETS - SCG - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 559	$ 960	$ 108
Accounts receivable – trade, net	2,071	1,578	1,261
Accounts receivable – other, net	398	403	455
Due from unconsolidated affiliates	23	20	32
Income taxes receivable, net	79	113	112
Inventories	389	308	277
Regulatory assets	271	190	222
Greenhouse gas allowances	97	553	72
Other current assets	209	149	163
Total current assets	4,375	4,511	3,339
Other assets:
Regulatory assets	2,011	1,822	1,930
Insurance receivable for Aliso Canyon costs	360	445	339
Greenhouse gas allowances	422	101	470
Right-of-use assets – operating leases	594	543	591
Other long-term assets	1,244	753	732
Total other assets	23,776	22,109	25,874
Property, plant and equipment:
Property, plant and equipment	58,940	53,928	49,329
Less accumulated depreciation and amortization	(15,046)	(13,925)	(12,877)
Property, plant and equipment, net	43,894	40,003	36,452
ASSETS	72,045	66,623	65,665
Current liabilities:
Short-term debt	3,471	885	3,505
Accounts payable – trade	1,671	1,359	1,234
Accounts payable – other	178	154	179
Due to unconsolidated affiliates	0	45	5
Accrued compensation and benefits	479	446	476
Regulatory liabilities	359	140	319
Current portion of long-term debt and finance leases	106	1,540	1,526
Reserve for Aliso Canyon costs	1,980	150	9
Greenhouse gas obligations	97	553	72
Other current liabilities	1,131	1,016	866
Total current liabilities	10,035	6,839	9,150
Long-term debt and finance leases	21,068	21,781	20,785
Deferred credits and other liabilities:
Regulatory liabilities	3,402	3,372	3,741
Reserve for Aliso Canyon costs	3	301	7
Greenhouse gas obligations	225	0	301
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	3,375	3,113	2,923
Deferred credits and other	2,067	2,119	2,062
Total deferred credits and other liabilities	13,523	13,069	13,925
Commitments and contingencies (Note 16)
Equity:
Common stock	11,862	7,053	7,480
Retained earnings	13,548	13,673	11,130
Accumulated other comprehensive income (loss)	(318)	(500)	(939)
Total shareholders’ equity	25,981	23,373	19,929
Total liabilities and shareholders’ equity	72,045	66,623	65,665
SoCalGas
Current assets:
Cash and cash equivalents	37	4	10
Accounts receivable – trade, net	1,084	786	710
Accounts receivable – other, net	58	64	87
Due from unconsolidated affiliates	49	22	11
Income taxes receivable, net	23	0	161
Inventories	172	153	136
Regulatory assets	40	16	7
Greenhouse gas allowances	75	390	52
Other current assets	61	47	44
Total current assets	1,599	1,482	1,218
Other assets:
Regulatory assets	1,148	1,208	1,407
Insurance receivable for Aliso Canyon costs	360	445	339
Greenhouse gas allowances	290	9	248
Right-of-use assets – operating leases	57	74	94
Other long-term assets	627	499	447
Total other assets	2,482	2,235	2,535
Property, plant and equipment:
Property, plant and equipment	23,104	21,180	19,362
Less accumulated depreciation and amortization	(6,861)	(6,437)	(6,038)
Property, plant and equipment, net	16,243	14,743	13,324
ASSETS	20,324	18,460	17,077
Current liabilities:
Short-term debt	385	113	630
Accounts payable – trade	775	600	545
Accounts payable – other	142	122	110
Due to unconsolidated affiliates	36	31	47
Accrued compensation and benefits	202	189	182
Regulatory liabilities	345	79	243
Current portion of long-term debt and finance leases	11	10	6
Customer deposits	13	48	71
Reserve for Aliso Canyon costs	1,980	150	9
Greenhouse gas obligations	75	390	52
Asset retirement obligations	77	59	65
Other current liabilities	271	291	222
Total current liabilities	4,312	2,082	2,182
Long-term debt and finance leases	4,773	4,763	3,788
Deferred credits and other liabilities:
Regulatory liabilities	1,100	1,177	1,422
Reserve for Aliso Canyon costs	3	301	7
Greenhouse gas obligations	174	0	208
Pension obligation, net of plan assets	551	853	785
Deferred income taxes	1,039	1,406	1,403
Asset retirement obligations	2,505	2,309	2,112
Deferred credits and other	425	425	422
Total deferred credits and other liabilities	5,797	6,471	6,359
Commitments and contingencies (Note 16)
Equity:
Preferred stock	22	22	22
Common stock	1,666	866	866
Retained earnings	3,785	4,287	3,883
Accumulated other comprehensive income (loss)	(31)	(31)	(23)
Total shareholders’ equity	5,442	5,144	4,748
Total liabilities and shareholders’ equity	20,324	18,460	17,077
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

CONSOLIDATED BALANCE SHEETS -_4

CONSOLIDATED BALANCE SHEETS - SCG (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925
SoCalGas
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	1,000,000	1,000,000	1,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,000,000	91,000,000	91,000,000

CONSOLIDATED STATEMENTS OF CA_3

CONSOLIDATED STATEMENTS OF CASH FLOWS - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$ 1,463	$ 4,105	$ 2,362
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes and investment tax credits	(78)	159	189
Impairment losses	3	1	43
Other	167	139	58
Net change in other working capital components:
Accounts receivable	(599)	(328)	(97)
Due to/from unconsolidated affiliates, net	(1)	12	1
Income taxes receivable/payable, net	(38)	(94)	(166)
Inventories	(87)	(35)	(22)
Other current assets	(220)	38	(88)
Accounts payable	263	74	17
Regulatory balancing accounts, net	249	(231)	13
Reserve for Aliso Canyon costs	1,532	141	(144)
Other current liabilities	(105)	(127)	(99)
Insurance receivable for Aliso Canyon costs	85	(106)	122
Reserve for Aliso Canyon costs, noncurrent	0	294	0
Changes in other noncurrent assets and liabilities, net	(496)	56	(399)
Net cash provided by operating activities	3,842	2,591	3,088
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,015)	(4,676)	(3,708)
Other	11	15	21
Net cash used in investing activities	(5,508)	553	(4,593)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,331)	(1,174)	(993)
Preferred dividends paid	(99)	(157)	(142)
Issuances of debt (maturities greater than 90 days)	3,773	6,051	4,296
Payments on debt (maturities greater than 90 days) and finance leases	(5,489)	(5,864)	(3,667)
Increase (decrease) in short-term debt, net	1,913	(1,759)	656
Net cash provided by financing activities	1,260	(2,373)	1,475
Increase (decrease) in cash and cash equivalents	(404)	768	(29)
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	1,163	1,046	1,051
Income tax payments (refunds), net	230	1,385	360
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	591	535	515
Increase in finance lease obligations for investment in PP&E	43	77	38
Increase in ARO for investment in PP&E	153	142	36
SoCalGas
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	(426)	505	642
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	716	654	602
Deferred income taxes and investment tax credits	(494)	(112)	88
Impairment losses	0	0	37
Other	19	59	(5)
Net change in other working capital components:
Accounts receivable	(383)	(101)	(73)
Due to/from unconsolidated affiliates, net	(25)	(27)	(1)
Income taxes receivable/payable, net	(43)	189	(156)
Inventories	(18)	(19)	1
Other current assets	(21)	(12)	(9)
Accounts payable	181	64	(7)
Regulatory balancing accounts, net	306	(160)	114
Reserve for Aliso Canyon costs	1,532	141	(144)
Other current liabilities	(92)	(21)	(21)
Insurance receivable for Aliso Canyon costs	85	(106)	122
Reserve for Aliso Canyon costs, noncurrent	0	294	0
Changes in other noncurrent assets and liabilities, net	(304)	178	(322)
Net cash provided by operating activities	1,033	1,526	868
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,984)	(1,843)	(1,439)
Other	0	0	1
Net cash used in investing activities	(1,984)	(1,843)	(1,438)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(75)	(100)	(150)
Preferred dividends paid	(1)	(1)	(1)
Equity contribution from Sempra Energy	800	0	0
Issuances of debt (maturities greater than 90 days)	0	949	349
Payments on debt (maturities greater than 90 days) and finance leases	(12)	(12)	(6)
Increase (decrease) in short-term debt, net	272	(517)	374
Debt issuance costs	0	(8)	(4)
Net cash provided by financing activities	984	311	562
Increase (decrease) in cash and cash equivalents	33	(6)	(8)
Cash and cash equivalents, January 1	4	10	18
Cash and cash equivalents, December 31	37	4	10
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	151	146	126
Income tax payments (refunds), net	227	19	188
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	222	208	205
Increase in finance lease obligations for investment in PP&E	19	47	22
Increase in ARO for investment in PP&E	$ 125	$ 107	$ 35

CONSOLIDATED STATEMENTS OF CH_5

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SCG - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Preferred stock	Preferred stockCumulative Effect, Period of Adoption, Adjusted Balance	Common stock	Common stockCumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings	Retained earningsCumulative Effect, Period of Adoption, Adjustment	Retained earningsCumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjusted Balance	SoCalGas	SoCalGasCumulative Effect, Period of Adoption, Adjustment	SoCalGasCumulative Effect, Period of Adoption, Adjusted Balance	SoCalGasPreferred stock	SoCalGasPreferred stockCumulative Effect, Period of Adoption, Adjusted Balance	SoCalGasCommon stock	SoCalGasCommon stockCumulative Effect, Period of Adoption, Adjusted Balance	SoCalGasRetained earnings	SoCalGasRetained earningsCumulative Effect, Period of Adoption, Adjustment	SoCalGasRetained earningsCumulative Effect, Period of Adoption, Adjusted Balance	SoCalGasAccumulated other comprehensive income (loss)	SoCalGasAccumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjustment	SoCalGasAccumulated other comprehensive income (loss)Cumulative Effect, Period of Adoption, Adjusted Balance
Beginning Balance at Dec. 31, 2018	$ 19,248		$ 19,263	$ 2,258	$ 2,258	$ 5,540	$ 5,540	$ 10,104		$ 10,161	$ (764)		$ (806)	$ 4,258		$ 4,256	$ 22	$ 22	$ 866	$ 866	$ 3,390		$ 3,392	$ (20)		$ (24)
Beginning Balance (Accounting Standards Update 2018-02) at Dec. 31, 2018		$ (2)							$ 40			$ (42)			$ (2)							$ 2			$ (4)
Net (loss) income	2,362							2,198						642							642
Other comprehensive income	(140)										(133)			1										1
Preferred stock dividends declared														(1)							(1)
Common stock dividends declared	(1,086)							(1,086)						(150)							(150)
Ending balance at Dec. 31, 2019	21,805		$ 21,796	2,258	$ 2,258	7,480	$ 7,480	11,130		$ 11,123	(939)		$ (939)	4,748			22		866		3,883			(23)
Net (loss) income	4,105							3,933						505							505
Other comprehensive income	422										446			(8)										(8)
Preferred stock dividends declared														(1)							(1)
Common stock dividends declared	(1,214)							(1,214)						(100)							(100)
Ending balance at Dec. 31, 2020	24,934			3,147		7,053		13,673			(500)			5,144			22		866		4,287			(31)
Net (loss) income	1,463							1,318						(426)							(426)
Other comprehensive income	171										160
Preferred stock dividends declared														(1)							(1)
Common stock dividends declared	(1,379)							(1,379)						(75)							(75)
Equity contribution from Sempra Energy														800					800
Ending balance at Dec. 31, 2021	$ 27,419			$ 889		$ 11,862		$ 13,548			$ (318)			$ 5,442			$ 22		$ 1,666		$ 3,785			$ (31)

CONSOLIDATED STATEMENTS OF CH_6

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SCG (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Common stock dividends declared (USD per share)	$ 4.40	$ 4.18	$ 3.87
Sale	$ 2,712	$ 28	$ 5
SoCalGas
Preferred stock, dividends declared per share (USD per share)	$ 1.50	$ 1.50	$ 1.50
Common stock dividends declared (USD per share)	$ 0.82	$ 1.10	$ 1.64

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Significant Accounting Policies And Other Financial Data	SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, a new segment that includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Through an internal reorganization, we consolidated the assets of our LNG business (previously included in our Sempra LNG segment) and our ownership of IEnova (previously included in our Sempra Mexico segment) under Sempra Global (previously included in Parent and other), which was renamed SI Partners. This reorganization simplifies Sempra’s ownership and management of its non-utility, energy infrastructure assets in North America by consolidating them under a single platform. As a result, the Sempra LNG and Sempra Mexico segments no longer exist. Our historical segment disclosures have been restated to conform with the current presentation, so that all discussions of our reportable segments reflect the revised segment information of our four separate reportable segments, which we discuss in Note 17. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E was the primary beneficiary until August 23, 2019, at which time SDG&E deconsolidated the VIE, as we discuss below in “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova, which is a wholly owned subsidiary of Sempra. SoCalGas SoCalGas’ common stock is wholly owned by PE, which is a wholly owned subsidiary of Sempra. BASIS OF PRESENTATION This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our,” “us” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We sometimes refer to SDG&E and SoCalGas collectively as Sempra California. SI Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity. Throughout these Notes, we refer to the following as Consolidated Financial Statements and Notes to Consolidated Financial Statements when discussed together or collectively: ▪ the Consolidated Financial Statements and related Notes of Sempra; ▪ the Consolidated Financial Statements and related Notes of SDG&E; and ▪ the Financial Statements and related Notes of SoCalGas. Use of Estimates in the Preparation of the Financial Statements We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates. Discontinued Operations We completed the sales of our equity interests in our Peruvian businesses in April 2020 and our Chilean businesses in June 2020. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria upon our decision to sell them in January 2019. These businesses are presented as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted. Subsequent Events We evaluated events and transactions that occurred after December 31, 2021 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation. REGULATED OPERATIONS SDG&E’s and SoCalGas’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, the FERC, requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Sempra Infrastructure’s natural gas distribution utility, Ecogas, also applies U.S. GAAP for rate-regulated utilities to its operations, including the same evaluation of probability of recovery of regulatory assets described above. Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and certain cities and are subject to regulatory rate-setting processes and earnings oversight. Oncor and Sharyland Utilities prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. Our Sempra Infrastructure segment includes the operating companies of our subsidiary, IEnova, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below in “Property, Plant and Equipment.” FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily NDT and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, short-term investments, and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and fixed-price electricity positions at SDG&E and the Support Agreement at Sempra Infrastructure. CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase. Restricted cash includes: ▪ for Sempra Infrastructure, funds denominated in Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects ▪ for Parent and other, funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) At December 31, 2021 2020 2019 Cash and cash equivalents $ 559 $ 960 $ 108 Restricted cash, current 19 22 31 Restricted cash, noncurrent 3 3 3 Cash, cash equivalents and restricted cash in discontinued operations — — 75 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 581 $ 985 $ 217 CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in a sales-type lease and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 6. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered. In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E and SoCalGas are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. As we discuss in Note 4, the CPUC authorized SDG&E and SoCalGas to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with customer protection measures ordered by the CPUC related to the COVID-19 pandemic. In connection with a separate CPUC decision addressing residential service disconnections, SDG&E and SoCalGas each established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP, as we discuss in Note 4. In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and will apply the amounts directly to eligible customer accounts to reduce past due balances. We provide below allowances and changes in allowances for credit losses for trade receivables and other receivables. SDG&E and SoCalGas record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts. RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Allowances for credit losses at January 1 $ 138 $ 29 $ 21 Incremental allowance upon adoption of ASU 2016-13 — 1 — Provisions for expected credit losses 45 124 22 Write-offs (47) (16) (14) Allowances for credit losses at December 31 $ 136 $ 138 $ 29 SDG&E: Allowances for credit losses at January 1 $ 69 $ 14 $ 11 Provisions for expected credit losses 23 65 10 Write-offs (26) (10) (7) Allowances for credit losses at December 31 $ 66 $ 69 $ 14 SoCalGas: Allowances for credit losses at January 1 $ 68 $ 15 $ 10 Provisions for expected credit losses 22 59 12 Write-offs (21) (6) (7) Allowances for credit losses at December 31 $ 69 $ 68 $ 15 Allowances for credit losses are included in the Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) December 31, 2021 2020 2019 Sempra: Accounts receivable – trade, net $ 94 $ 111 $ 7 Accounts receivable – other, net 39 27 22 Other long-term assets 3 — — Total allowances for credit losses $ 136 $ 138 $ 29 SDG&E: Accounts receivable – trade, net $ 42 $ 55 $ 4 Accounts receivable – other, net 22 14 10 Other long-term assets 2 — — Total allowances for credit losses $ 66 $ 69 $ 14 SoCalGas: Accounts receivable – trade, net $ 51 $ 55 $ 3 Accounts receivable – other, net 17 13 12 Other long-term assets 1 — — Total allowances for credit losses $ 69 $ 68 $ 15 As we discuss below in “Transactions with Affiliates,” we have loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on amounts due from unconsolidated affiliates, if necessary, based on credit quality indicators such as external credit ratings, published default rate studies, the maturity date of the instrument and past delinquencies. However, we do not record allowances for expected credit losses related to accrued interest receivable on loans due from unconsolidated affiliates because we write off such amounts, if any, through a reversal of interest income in the period we determine such amounts are uncollectible. In the absence of external credit ratings, we may utilize an internally developed credit rating based on our analysis of a counterparty’s financial statements to determine our expected credit losses. At December 31, 2021 and 2020, $1 million and $3 million, respectively, of expected credit losses are included in noncurrent Due From Unconsolidated Affiliates on Sempra’s Consolidated Balance Sheets. As we discuss below in “Note Receivable,” Sempra loaned $300 million to KKR in exchange for an interest-bearing promissory note. We evaluate credit losses and record allowances for expected credit losses on this note receivable based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At December 31, 2021, $8 million of expected credit losses is included in Other Long-Term Assets on Sempra’s Consolidated Balance Sheet. As we discuss below in Note 6, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra Infrastructure from the SDSRA. At December 31, 2021, expected credit losses of $7 million related to this guarantee are included in Deferred Credits and Other on Sempra’s Consolidated Balance Sheet. CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by the respective credit departments at each of our segments and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a regular basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: ▪ prospective counterparties’ financial condition (including credit ratings) ▪ collateral requirements ▪ the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty ▪ downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance in our allowances for credit losses. When our development projects become operational, we rely significantly on the ability of suppliers to perform under long-term agreements and on our ability to enforce contract terms in the event of nonperformance. Also, the factors that we consider in evaluating a development project include negotiating customer and supplier agreements and, therefore, we rely on these agreements for future performance. We also may condition our decision to go forward on development projects on first obtaining these customer and supplier agreements. INVENTORIES SDG&E and SoCalGas value natural gas inventory using the last-in first-out method. As inventories are sold, differences between the last-in first-out valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent if the natural gas inventory withdrawn from storage during the year is not replaced by year end. SDG&E and SoCalGas generally value materials and supplies at the lower of average cost or net realizable value. Sempra Infrastructure values natural gas inventory and materials and supplies at the lower of average cost or net realizable value, and LNG inventory using the first-in first-out method. The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2021 2020 2019 2021 2020 2019 2021 2020 2019 Natural gas $ 164 $ 118 $ 110 $ — $ — $ 1 $ 114 $ 94 $ 90 LNG 27 7 9 — — — — — — Materials and supplies 198 183 158 123 104 93 58 59 46 Total $ 389 $ 308 $ 277 $ 123 $ 104 $ 94 $ 172 $ 153 $ 136 NOTE RECEIVABLE In connection with the KKR Purchase Agreement, which we define and discuss below in “Noncontrolling Interests,” we entered into an accommodation and support agreement under which KKR issued a $300 million interest bearing promissory note to Sempra in exchange for cash. Loan-related transaction costs incurred by KKR totaled $5 million, which were reimbursed by Sempra per the terms of the agreement. The promissory note is due to be repaid in full no later than October 1, 2029 and bears compound interest at 5% per annum, which may be paid quarterly or added to the outstanding principal at the election of KKR. At December 31, 2021, Other Long-Term Assets includes $297 million of outstanding principal, net of allowance for credit losses, and Other Current Assets includes $3 million of interest receivable on Sempra’s Consolidated Balance Sheet. WILDFIRE FUND In July 2019, the Wildfire Legislation was signed into law. The Wildfire Legislation addresses certain issues related to catastrophic wildfires in the State of California and their impact on electric IOUs. Investor-owned gas distribution utilities such as SoCalGas are not covered by this legislation. The issues addressed include wildfire mitigation, cost recovery standards and requirements, a wildfire fund, a cap on liability, and the establishment of a wildfire safety board. The Wildfire Legislation provided that SDG&E would not recover the ROE on its first $215 million of fire risk mitigation capital expenditures. The Wildfire Legislation established a revised legal standard for the recovery of wildfire costs (Revised Prudent Manager Standard) and established a fund (the Wildfire Fund) designed to provide liquidity to SDG&E, PG&E and Edison to pay IOU wildfire-related claims in the event that the governmental agency responsible for determining causation determines the applicable IOU’s equipment caused the ignition of a wildfire, primary insurance coverage is exceeded and certain other conditions are satisfied. A primary purpose of the Wildfire Fund is to pool resources provided by shareholders and ratepayers of the IOUs and make those resources available to reimburse the IOUs for third-party wildfire claims incurred after July 12, 2019, the effective date of the Wildfire Legislation, subject to certain limitations. An IOU may seek payment from the Wildfire Fund for settled or adjudicated third-party damage claims arising from certain wildfires that exceed, in aggregate in a calendar year, the greater of $1 billion or the IOU’s required amount of insurance coverage as recommended by the Wildfire Fund’s administrator. Wildfire claims approved by the Wildfire Fund’s administrator will be paid by the Wildfire Fund to the IOU to the extent funds are available. These utilized funds will be subject to review by the CPUC, which will make a determination as to the degree an IOU’s conduct related to an ignition of a wildfire was prudent or imprudent. The Revised Prudent Manager Standard requires that the CPUC apply clear standards when reviewing wildfire liability losses paid when determining the reasonableness of an IOU’s conduct related to an ignition. Under this standard, the conduct under review related to the ignition may include factors within and beyond the IOU’s control, including humidity, temperature and winds. Costs and expenses may be allocated for cost recovery in full or in part. Also, under this standard, an IOU’s conduct will be deemed reasonable if a valid annual safety certification is in place at the time of the ignition, unless a serious doubt is raised, in which case the burden shifts to the utility to dispel that doubt. The IOUs will receive an annual safety certification from the CPUC if they meet various requirements. If an IOU has maintained a valid annual safety certification, to the extent it is found to be imprudent, claims will be reimbursable by the IOU to the Wildfire Fund up to a cap based on the IOU’s rate base. The aggregate requirement to reimburse the Wildfire Fund over a trailing three calendar year period is capped at 20% of the equity portion of an IOU’s electric transmission and distribution rate base in the year of the prudency determination. Based on its 2021 rate base, the liability cap for SDG&E is approximately $1.1 billion, which is adjusted annually. The liability cap will apply on a rolling three-year basis so long as future annual safety certifications are received and the Wildfire Fund has not been terminated, which could occur if funds are exhausted. Amounts in excess of the liability cap and amounts that are determined to be prudently incurred do not need to be reimbursed by an IOU to the Wildfire Fund. The Wildfire Fund does not have a specified term and coverage will continue until the assets of the Wildfire Fund are exhausted and the Wildfire Fund is terminated, in which case, the remaining funds, if any, will be transferred to California’s general fund to be used for fire risk mitigation programs. In July 2021, the CPUC approved SDG&E’s 2021 Wildfire Mitigation Plan. In July 2021, the CPUC’s Wildfire Safety Division became the OEIS under the California Natural Resources Agency. As successor to the Wildfire Safety Division, the OEIS maintains the duties and responsibilities of the former Wildfire Safety Division with respect to Wildfire Mitigation Plans. The 2021 Wildfire Mitigation Plan is effective until the OEIS approves a new plan. In December 2021, SDG&E received its 2021 wildfire safety certification from the OEIS, which is valid for 12 months from the issue date. The Wildfire Fund was initially funded up to $10.5 billion by a loan from the State of California Surplus Money Investment Fund. The loan is financed through a DWR bond, which was put in place on October 1, 2020 and is securitized through a dedicated surcharge on ratepayers’ bills attributable to the DWR. In October 2019, the CPUC adopted a decision authorizing a non-bypassable charge to be collected by the IOUs to support the anticipated DWR bond issuance authorized by AB 1054. The CPUC decision also determined that ratepayers of non-participating electrical corporations shall not pay the non-bypassable charge. The Wildfire Fund was also funded by initial shareholder contributions from the IOUs totaling $7.5 billion. SDG&E’s share was $322.5 million. The IOUs are also required to make annual shareholder contributions to the Wildfire Fund with an aggregate value of $3 billion over a 10-year period starting in 2019. SDG&E’s share is $129 million. The contributions are not subject to rate recovery. In a complaint filed in U.S. District Court for the Northern District of California in July 2019, plaintiffs seek to invalidate AB 1054 based on allegations that the legislation violates federal law. The district court and, subsequently, the U.S. Court of Appeals for the Ninth Circuit dismissed the complaint. Wildfire Fund Asset and Obligation In 2019, SDG&E recorded both a Wildfire Fund asset and a related obligation for its commitment to make shareholder contributions of $451.5 million to the Wildfire Fund, measured at present value as of July 25, 2019 (the date by which both Edison and SDG&E opted to contribute to the Wildfire Fund). SDG&E paid its initial shareholder contribution of $322.5 million to the Wildfire Fund in September 2019. SDG&E funded this contribution with proceeds from an equity contribution from Sempra. SDG&E expects to continue to make annual shareholder contributions of $12.9 million through December 31, 2028. SDG&E accretes the present value of the Wildfire Fund obligation until the liability is settled. SDG&E is amortizing the Wildfire Fund asset on a straight-line basis over the estimated period of benefit, as adjusted for utilization by the IOUs. The estimated period of benefit of the Wildfire Fund asset is 15 years and is based on several assumptions, including, but not limited to: ▪ historical wildfire experience of each IOU in the State of California, including frequency and severity of the wildfires ▪ the value of property potentially damaged by wildfires ▪ the effectiveness of wildfire risk mitigation efforts by each IOU ▪ liability cap of each IOU ▪ IOU prudency determination levels ▪ FERC jurisdictional allocation levels ▪ insurance coverage levels The use of different assumptions, or changes to the assumptions used, could have a significant impact on the estimated period of benefit of the Wildfire Fund asset. SDG&E periodically evaluates the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in these assumptions. SDG&E recognizes a reduction of its Wildfire Fund asset and records a charge against earnings in the period when there is a reduction of the available coverage due to recoverable claims from any of the participating IOUs. Wildfire claims that are recoverable from the Wildfire Fund, net of anticipated or actual reimbursement to the Wildfire Fund by the responsible IOU, decrease the Wildfire Fund asset and remaining available coverage. The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2021 2020 2019 Wildfire Fund asset: Current Prepaid Expenses $ 29 $ 29 $ 29 Noncurrent Wildfire Fund 331 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 $ 13 Noncurrent Deferred Credits and Other 64 75 86 Years ended December 31, 2021 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 29 $ 12 Impairment of Wildfire Fund asset Impairment Losses (1) 3 — — Accretion of Wildfire Fund obligation Operation and Maintenance 2 2 1 (1) Included in O&M for SDG&E. INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. Investment tax credits from prior years are amortized to income by SDG&E and SoCalGas over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, SDG&E, SoCalGas and Sempra Infrastructure recognize: ▪ regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪ regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR. We accrue income tax to the extent we intend to repatriate cash to the U.S. from our continuing international operations. We currently do not record deferred income taxes for other basis differences between financial st

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2021
Accounting Changes and Error Corrections [Abstract]
New Accounting Standards	NEW ACCOUNTING STANDARDS We describe below recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures. ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts.

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUESThe following table disaggregates our revenues from contracts with customers by major service line and market and provides a reconciliation to total revenues by segment. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Sempra Infrastructure Sempra Renewables Consolidating adjustments and Parent and other Sempra Year ended December 31, 2021 By major service line: Utilities $ 5,144 $ 5,424 $ 81 $ — $ (109) $ 10,540 Energy-related businesses — — 1,165 — (29) 1,136 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 By market: Gas $ 790 $ 5,424 $ 856 $ — $ (101) $ 6,969 Electric 4,354 — 390 — (37) 4,707 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 Utilities regulatory revenues 360 91 — — — 451 Other revenues — — 751 — (21) 730 Total revenues $ 5,504 $ 5,515 $ 1,997 $ — $ (159) $ 12,857 Year ended December 31, 2020 By major service line: Utilities $ 4,920 $ 4,571 $ 58 $ — $ (94) $ 9,455 Energy-related businesses — — 854 — 1 855 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 By market: Gas $ 692 $ 4,571 $ 623 $ — $ (90) $ 5,796 Electric 4,228 — 289 — (3) 4,514 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 Utilities regulatory revenues 393 177 — — — 570 Other revenues — — 488 — 2 490 Total revenues $ 5,313 $ 4,748 $ 1,400 $ — $ (91) $ 11,370 Year ended December 31, 2019 By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ (75) $ 9,184 Energy-related businesses — — 951 5 1 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 By market: Gas $ 587 $ 4,367 $ 711 $ — $ (69) $ 5,596 Electric 4,232 — 313 5 (5) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 Utilities regulatory revenues 106 158 — — — 264 Other revenues — — 430 5 (11) 424 Total revenues $ 4,925 $ 4,525 $ 1,454 $ 10 $ (85) $ 10,829 REVENUES FROM CONTRACTS WITH CUSTOMERS Our revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity service is provided to our customers and we invoice our customers for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Our performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of our performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in our customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ ability to collect from the customer, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: ▪ The transmission, distribution and storage of natural gas at: ◦ SDG&E ◦ SoCalGas ◦ Sempra Infrastructure’s Ecogas ▪ The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill our customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, which follow the provisions of U.S. GAAP governing rate-regulated operations as we discuss in Note 1, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue for customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. SDG&E and SoCalGas recognize revenues from the sale of allocated California GHG emissions allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and SDG&E and SoCalGas have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Revenues at Sempra Infrastructure typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. As we discuss in Note 5, in February 2019, Sempra Infrastructure completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas). We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency translation and the actual quantity of commodity transported. Sempra Infrastructure and, previously, Sempra Renewables develop, invest in and operate solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, and also for Sempra Infrastructure, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated and delivered. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. As we discuss in Note 5, in April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities, as the power is delivered at the interconnection point. Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure. SoCalGas did not have any remaining performance obligations at December 31, 2021. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2022 $ 368 $ 4 2023 367 4 2024 365 4 2025 362 4 2026 361 4 Thereafter 4,289 63 Total revenues to be recognized $ 6,112 $ 83 (1) Excludes intercompany transactions. Contract Liabilities from Revenues from Contracts with Customers From time to time, we receive payments in advance of satisfying the performance obligations associated with customer contracts. We defer such revenues as contract liabilities and recognize them in earnings as the performance obligations are satisfied. Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in 2021, 2020 or 2019. CONTRACT LIABILITIES (Dollars in millions) 2021 2020 2019 Sempra: Contract liabilities at January 1 $ (207) $ (163) $ (70) Revenue from performance obligations satisfied during reporting period 52 4 2 Payments received in advance (123) (48) (95) Contract liabilities at December 31 (1) $ (278) $ (207) $ (163) SDG&E: Contract liabilities at January 1 $ (87) $ (91) $ — Revenue from performance obligations satisfied during reporting period 4 4 1 Payments received in advance — — (92) Contract liabilities at December 31 (2) $ (83) $ (87) $ (91) (1) Balances at December 31, 2021, 2020 and 2019 include $116, $52 and $4, respectively, in Other Current Liabilities and $162, $155 and $159, respectively, in Deferred Credits and Other. (2) Balances at December 31, 2021, 2020 and 2019 include $4, $4 and $4, respectively, in Other Current Liabilities and $79, $83 and $87, respectively, in Deferred Credits and Other. Receivables from Revenues from Contracts with Customers The table below shows receivable balances associated with revenues from contracts with customers on the Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2021 2020 2019 Sempra: Accounts receivable – trade, net $ 1,886 $ 1,447 $ 1,163 Accounts receivable – other, net 19 12 16 Due from unconsolidated affiliates – current (1) 2 3 5 Other long-term assets 70 — — Total $ 1,977 $ 1,462 $ 1,184 SDG&E: Accounts receivable – trade, net $ 715 $ 573 $ 398 Accounts receivable – other, net 9 8 5 Due from unconsolidated affiliates – current (1) 2 2 2 Other long-term assets 25 — — Total $ 751 $ 583 $ 405 SoCalGas: Accounts receivable – trade, net $ 1,084 $ 786 $ 710 Accounts receivable – other, net 10 4 11 Other long-term assets 45 — — Total $ 1,139 $ 790 $ 721 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Consolidated Balance Sheets, when right of offset exists. In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E and SoCalGas are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and will apply the amounts directly to eligible customer accounts to reduce past due balances. REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled revenues. As discussed earlier, the regulatory framework requires SDG&E and SoCalGas to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive mechanisms. The CPUC applies performance-based measures and incentive mechanisms to all California IOUs, under which SDG&E and SoCalGas have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize SDG&E and SoCalGas to collect revenue requirements for operating costs and capital related costs (such as depreciation, taxes and return on rate base) from customers, including: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded within a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met at the time the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund for programs authorized, including limitations on the total cost of the program, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in disallowances of recovery from ratepayers. We discuss balancing accounts and their effects further in Note 4. Other Revenues Sempra Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and liquid fuels terminals. Certain PPAs at Sempra Renewables were accounted for as operating leases prior to sale of its wind assets in April 2019. We discuss the recognition of lease income in Note 16 of the Notes to Consolidated Financial Statements. Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes. Sempra Infrastructure also recognizes other revenues associated with derivatives related to the sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of these derivatives.

REGULATORY MATTERS

REGULATORY MATTERS	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2021 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (50) $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 125 22 (108) Pension and other postretirement benefit plan obligations (7) 50 103 Removal obligations (2,251) (2,121) (2,056) Environmental costs 62 56 45 Sunrise Powerlink fire mitigation 122 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 77 72 102 Gas transportation 49 35 22 Safety and reliability 67 67 77 Public purpose programs (107) (158) (124) 2019 GRC retroactive impacts — 56 111 Wildfire mitigation plan 178 93 12 Liability insurance premium 110 79 24 Other balancing accounts 207 61 70 Other regulatory assets (liabilities), net (2) 119 72 (153) Total SDG&E (1,299) (1,548) (1,746) SoCalGas: Deferred income taxes recoverable (refundable) in rates 44 (82) (203) Pension and other postretirement benefit plan obligations 51 417 400 Employee benefit costs 31 37 44 Removal obligations (627) (685) (728) Environmental costs 34 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (146) (56) (118) Safety and reliability 339 335 295 Public purpose programs (183) (253) (273) 2019 GRC retroactive impacts — 202 400 Liability insurance premium 16 7 4 Other balancing accounts 42 (65) (11) Other regulatory assets (liabilities), net (2) 142 75 (101) Total SoCalGas (257) (32) (251) Sempra Infrastructure: Deferred income taxes recoverable in rates 77 80 83 Other regulatory assets — — 6 Total Sempra $ (1,479) $ (1,500) $ (1,908) (1) At December 31, 2021, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $358, $139 and $108, respectively, and for SoCalGas was $410, $218 and $500, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. Regulatory Assets Not Earning a Return ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. The related amounts are recovered in rates once these contracts are settled, generally within two years. ▪ Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Infrastructure expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include excess deferred income taxes resulting from statutory income tax rate changes and certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 8. ▪ Regulatory assets/liabilities related to pension and other postretirement benefit plan obligations are offset by corresponding liabilities/assets. The assets are recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 48-year period. Regulatory Assets Earning a Return ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized amounts. Depreciation, taxes and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. The adopted revenue requirements in the 2019 GRC FD associated with the period from January 1, 2019 through December 31, 2019 were recovered in rates over a 24-month period that began in January 2020. Amortization expense on certain regulatory assets for the years ended December 31, 2021, 2020 and 2019 was $10 million, $9 million and $7 million, respectively, at Sempra, $5 million, $4 million and $3 million, respectively, at SDG&E, and $5 million, $5 million and $4 million, respectively, at SoCalGas. SEMPRA CALIFORNIA COVID-19 Pandemic Protections In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E and SoCalGas are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and will apply the amounts directly to eligible customer accounts to reduce past due balances. SDG&E and SoCalGas have been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. SDG&E and SoCalGas expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in future CPUC proceedings, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below. Disconnection OIR In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, SDG&E and SoCalGas have each established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. CPUC GRC The CPUC uses GRCs to set rates designed to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. In September 2019, the CPUC issued a final decision in the 2019 GRC approving SDG&E’s and SoCalGas’ test year revenues for 2019 and attrition year adjustments for 2020 and 2021, which was effective retroactively to January 1, 2019. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD approved a test year 2019 revenue requirement of $1,990 million for SDG&E’s combined operations ($1,590 million for its electric operations and $400 million for its natural gas operations) and $2,770 million for SoCalGas. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs. SDG&E and SoCalGas were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). In May 2021, the CPUC issued a final decision approving SDG&E’s and SoCalGas’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023. The 2019 GRC FD approved SDG&E’s and SoCalGas’ establishment of two-way liability insurance premium balancing accounts, including wildfire insurance premium costs based on a specific level of coverage. The 2019 GRC FD also permits SDG&E and SoCalGas to seek recovery of additional liability insurance coverage. The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time SDG&E and SoCalGas released these regulatory liability balances to revenues and regulatory interest. CPUC Cost of Capital A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 % The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index. Alternatively, under the CCM, SDG&E and SoCalGas are permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022. For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SDG&E and SoCalGas are required to file their next cost of capital applications in April 2022 for a January 1, 2023 effective date. SDG&E FERC Rate Matters SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar quarter until terminated by a notice at least six months before the end of the calendar year. In 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. Energy Efficiency Program Inquiry In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive. Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded that some concessions were appropriate, which include refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the year ended December 31, 2020, SDG&E reduced revenues by $51 million and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Consolidated Statements of Operations. The after-tax impact for the year ended December 31, 2020 was $44 million. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement. SOCALGAS OSCs – Energy Efficiency and Advocacy In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. On February 3, 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 can be appealed within 30 days or be reviewed by any of the CPUC commissioners. If there are no appeals or commissioner requests for review, POD 1 automatically becomes the final decision of the CPUC. SoCalGas does not intend to appeal POD 1. In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, the assigned Administrative Law Judge issued a modified POD 2 that substantially retains the original conclusions, including no fines or penalties. Also, in February 2022, a CPUC commissioner issued an alternative decision that imposes a financial penalty of $150,000. SoCalGas expects that both the modified POD 2 and the CPUC commissioner’s alternative decision will be heard at a CPUC meeting in March 2022. If the CPUC were to assess fines, penalties or other restrictions on SoCalGas that are different from what has been ordered in POD 1 and the modified POD 2, they could be material to SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra’s and SDG&E’s Consolidated Statements of Operations. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost. The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the foundation filed a notice of appeal. In September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the CCC’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. In December 2021, the foundation filed a request for dismissal. To date, decommissioning work has not been interrupted as a result of these writ petitions. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In December 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 12. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated At December 31, 2021: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 56 $ — $ — $ 56 Municipal bonds (2) 309 13 (1) 321 Other securities (3) 255 7 (2) 260 Total debt securities 620 20 (3) 637 Equity securities 104 262 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net 8 — — 8 Total $ 735 $ 282 $ (5) $ 1,012 At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 64 $ 1 $ — $ 65 Municipal bonds 308 18 — 326 Other securities 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Short-term investments, primarily cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2052. (2) Maturity dates are 2022-2056. (3) Maturity dates are 2022-2072. The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Proceeds from sales $ 961 $ 1,439 $ 914 Gross realized gains 67 156 24 Gross realized losses (5) (17) (5) Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. ASSET RETIREMENT OBLIGATION The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $568 million at December 31, 2021 and is based on a cost study prepared in 2020, which will be submitted to the CPUC in the first half of 2022. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $79 million in 2022, $66 million in 2023, $77 million in 2024, $46 million in 2025, $52 million in 2026, and $718 million thereafter. U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018, which is pending DOE approval. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.3 million of retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

ACQUISTIONS, DIVESTITURES AND D

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS	ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS ACQUISITIONS Sempra Texas Utilities Sharyland Holdings In May 2019, Sempra acquired an indirect, 50% interest in Sharyland Holdings for $95 million (net of $7 million in post-closing adjustments). In connection with and prior to the consummation of the acquisition, Sharyland Holdings owned 100% of the membership interests in Sharyland Utilities, LP and Sharyland Utilities, LP converted into a limited liability company, named Sharyland Utilities, L.L.C. We account for our indirect, 50% interest in Sharyland Holdings as an equity method investment. Sempra Infrastructure ESJ In March 2021, Sempra Infrastructure completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of $65 million (net of $14 million of acquired cash and cash equivalents) plus the assumption of $277 million in debt (including $94 million owed from ESJ to Sempra Infrastructure that eliminates upon consolidation). Sempra Infrastructure previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased Sempra Infrastructure’s ownership interest in ESJ from 50% to 100%. We accounted for this asset acquisition using a cost accumulation model whereby the cost of the acquisition and carrying value of our previously held interest in ESJ ($34 million) were allocated to assets acquired ($458 million) and liabilities assumed ($345 million) based on their relative fair values. ESJ owns a fully operating wind power generation facility with a nameplate capacity of 155 MW that is fully contracted by SDG&E under a long-term PPA. Sempra Infrastructure recorded a $190 million intangible asset for the relative fair value of the PPA that will be amortized over a period of 14 years against revenues. On January 15, 2022, ESJ completed construction and began commercial operation of a second wind power generation facility with a nameplate capacity of 108 MW that is also fully contracted by SDG&E under a long-term PPA. DIVESTITURES Sempra Infrastructure In February 2019, Sempra Infrastructure completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas), which we classified as held for sale at December 31, 2018, and received cash proceeds of $322 million, net of transaction costs. In January 2019, Sempra Infrastructure completed the sale of other non-utility assets for $5 million. Sempra Renewables In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments for $569 million, net of transaction costs, and recorded a $61 million ($45 million after tax and NCI) gain, which is included in Gain on Sale of Assets on Sempra’s Consolidated Statements of Operations. Upon completion of the sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. Parent and Other PXiSE In December 2021, Parent and other completed the sale of its 80% interest in PXiSE for total cash proceeds of $38 million, net of transaction costs totaling $4 million, and recorded a $36 million ($26 million after tax) gain, which is included in Gain (Loss) on Sale of Assets on Sempra’s Consolidated Statement of Operations. DISCONTINUED OPERATIONS In January 2019, our board of directors approved a plan to sell our South American businesses. We present these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with those businesses as discontinued operations. In April 2020, we completed the sale of our equity interests in our Peruvian businesses, including our 83.6% interest in Luz del Sur and our interest in Tecsur, to an affiliate of China Yangtze Power International (Hongkong) Co., Limited for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $2,271 million ($1,499 million after tax). In June 2020, we completed the sale of our equity interests in our Chilean businesses, including our 100% interest in Chilquinta Energía and Tecnored and our 50% interest in Eletrans, to State Grid International Development Limited for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $628 million ($248 million after tax). In the year ended December 31, 2020, the pretax gains from the sales of our South American businesses are included in Gain on Sale of Discontinued Operations in the table below and the after-tax gains are included in Income from Discontinued Operations, Net of Income Tax, on Sempra’s Consolidated Statements of Operations. Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Years ended December 31, 2020 (1) 2019 Revenues $ 570 $ 1,614 Cost of sales (364) (1,012) Gain on sale of discontinued operations 2,899 — Operating expenses (66) (159) Interest and other (3) (11) Income before income taxes and equity earnings 3,036 432 Income tax expense (1,186) (72) Equity earnings — 3 Income from discontinued operations, net of income tax 1,850 363 Earnings attributable to noncontrolling interests (10) (35) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 (1) Results include activity until deconsolidation of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020 and post-closing adjustments related to the sales of these businesses. The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations. ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS (Dollars in millions) December 31, 2019 Cash and cash equivalents $ 74 Restricted cash (1) 1 Accounts receivable, net 303 Due from unconsolidated affiliates 2 Inventories 36 Other current assets 29 Current assets $ 445 Due from unconsolidated affiliates $ 54 Goodwill and other intangible assets 801 Property, plant and equipment, net 2,618 Other noncurrent assets 40 Noncurrent assets $ 3,513 Short-term debt $ 52 Accounts payable 201 Current portion of long-term debt and finance leases 85 Other current liabilities 106 Current liabilities $ 444 Long-term debt and finance leases $ 702 Deferred income taxes 284 Other noncurrent liabilities 66 Noncurrent liabilities $ 1,052 (1) Primarily represents funds held in accordance with Peruvian tax law. As a result of the sales of our South American businesses, in 2020, we reclassified $645 million of cumulative foreign currency translation losses from AOCI to Gain on Sale of Discontinued Operations, which is included in Income from Discontinued Operations, Net of Income Tax, on Sempra’s Consolidated Statements of Operations.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	12 Months Ended
	Dec. 31, 2021
Investments [Abstract]
INVESTMENTS IN UNCONSOLIDATED ENTITIES	INVESTMENTS IN UNCONSOLIDATED ENTITIES We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Consolidated Statements of Operations. Our equity method investments include various domestic and foreign entities. Our domestic equity method investees are typically partnerships that are pass-through entities for income tax purposes and therefore they do not record income tax. Sempra’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense on the Consolidated Statements of Operations. Our foreign equity method investees are generally corporations whose operations are taxable on a standalone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax. See Note 8 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR. We provide the carrying values of our investments and earnings (losses) on these investments in the following tables. EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) Percent ownership December 31, December 31, 2021 2020 2019 2021 2020 2019 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % 100 % $ 12,947 $ 12,440 $ 11,519 Sempra Texas Utilities: Sharyland Holdings (2) 50 50 50 $ 100 $ 102 $ 100 Sempra Infrastructure: Cameron LNG JV (3) 50.2 50.2 50.2 514 433 1,256 ESJ JV (4) — 50 50 — 34 39 IMG JV (5) 40 40 40 523 440 337 TAG JV (6) 50 50 50 388 378 365 Total other equity method investments 1,525 1,387 2,097 Other — 1 6 Total other investments $ 1,525 $ 1,388 $ 2,103 (1) The carrying value of our equity method investment is $2,844, $2,833 and $2,823 higher than the underlying equity in the net assets of the investee at December 31, 2021, 2020 and 2019, respectively, due to $2,868 of equity method goodwill and $69 in basis differences in AOCI, offset by $93, $104 and $114 at December 31, 2021, 2020 and 2019, respectively, due to a tax sharing liability to TTI under a tax sharing agreement. (2) The carrying value of our equity method investment is $42 higher than the underlying equity in the net assets of the investee due to equity method goodwill. (3) The carrying value of our equity method investment is $276, $259 and $263 higher than the underlying equity in the net assets of the investee at December 31, 2021, 2020 and 2019, respectively, primarily due to guarantees, which we discuss below, interest capitalized on the investment prior to the JV commencing its planned principal operations in August 2019 and amortization of guarantee fees and capitalized interest thereafter. (4 ) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. After the acquisition, ESJ is no longer accounted for as an equity method investment. The carrying value of our equity method investment is $12 higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019 due to the remeasurement of our retained investment to fair value in 2014. (5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees. (6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2021 2020 2019 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 5 $ 3 $ 2 Sempra Infrastructure: Cameron LNG JV (2) 559 391 24 Sempra Renewables: Wind assets — — 5 Parent and other: RBS Sempra Commodities 50 (100) — Other — — (1) 614 294 30 EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 617 577 526 Sempra Infrastructure: ESJ JV 2 5 2 IMG JV 83 103 9 TAG JV 27 36 13 729 721 550 Total $ 1,343 $ 1,015 $ 580 (1) We provide our ETR calculation in Note 8. (2) Includes $3 of basis differences in equity earnings related to AOCI in 2021. We disclose distributions received from our investments, by segment, in the table below. DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra Texas Utilities $ 688 $ 286 $ 246 Sempra Infrastructure 672 1,176 2 Sempra Renewables — — 1 Parent and other — — 7 Total $ 1,360 $ 1,462 $ 256 SEMPRA TEXAS UTILITIES Oncor Holdings We account for our 100% ownership interest in Oncor Holdings, which owns an 80.25% interest in Oncor, as an equity method investment. Sempra does not control Oncor Holdings or Oncor, and the ring-fencing measures, governance mechanisms and commitments in effect limit our ability to direct the management, policies and operations of Oncor Holdings and Oncor, including the deployment or disposition of their assets, declarations of dividends, strategic planning and other important corporate issues and actions. We also have limited representation on the Oncor Holdings and Oncor boards of directors. Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra. Rather, only our pretax equity earnings from our investment in Oncor Holdings (a disregarded entity for tax purposes) are included in our consolidated income tax return. A tax sharing agreement with TTI, Oncor Holdings and Oncor provides for the calculation of an income tax liability substantially as if Oncor Holdings and Oncor were taxed as corporations and requires tax payments determined on that basis. While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and Oncor being subject to the provisions of U.S. GAAP governing rate-regulated operations, Oncor recognizes amounts determined under cost-based regulatory rate-setting processes (with such costs including income taxes), as if it were taxed as a corporation. As a result, since Oncor Holdings consolidates Oncor, we recognize equity earnings from our investment in Oncor Holdings net of its recorded income tax. We provide summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Year ended December 31, 2021 2020 2019 Operating revenues $ 4,764 $ 4,511 $ 4,347 Operating expense (3,397) (3,224) (3,135) Income from operations 1,367 1,287 1,212 Interest expense (413) (405) (375) Income tax expense (163) (146) (131) Net income 760 703 643 Noncontrolling interest held by TTI (152) (141) (129) Earnings attributable to Sempra (1) 608 562 514 At December 31, 2021 2020 2019 Current assets $ 1,039 $ 1,045 $ 913 Noncurrent assets 29,481 28,022 26,012 Current liabilities 2,220 1,120 1,626 Noncurrent liabilities 15,281 15,611 14,125 Noncontrolling interest held by TTI 2,916 2,737 2,473 (1) Excludes adjustments to equity earnings related to amortization of a tax sharing liability associated with a tax sharing arrangement and changes in basis differences in AOCI within the carrying value of our equity method investment. In 2021, 2020 and 2019, Sempra contributed $566 million, $632 million and $1,587 million, respectively, to Oncor Holdings, including $1,067 million in 2019 to fund Oncor’s May 2019 acquisition of interests in InfraREIT and certain acquisition-related expenses. Sharyland Holdings As we discuss in Note 5, in May 2019, we acquired an indirect, 50% interest in Sharyland Holdings, which owns a 100% interest in Sharyland Utilities, for $95 million, net of $7 million in post-closing adjustments, which we account for as an equity method investment. In 2019, we invested cash of $3 million in Sharyland Holdings. SEMPRA INFRASTRUCTURE Cameron LNG JV Cameron LNG JV was formed in October 2014 and is a JV between Sempra and three project partners, TotalEnergies SE, Mitsui & Co., Ltd., and Japan LNG Investment, LLC, a company jointly owned by Mitsubishi Corporation and Nippon Yusen Kabushiki Kaisha. We account for our 50.2% investment in Cameron LNG JV under the equity method. Cameron LNG JV operates a three-train natural gas liquefaction export facility with a nameplate capacity of 13.9 Mtpa of LNG, with an export capacity of 12 Mtpa of LNG, or approximately 1.7 Bcf per day. Cameron LNG JV achieved commercial operations of Train 1, Train 2 and Train 3 under its tolling agreements in August 2019, February 2020 and August 2020, respectively. Prior to commencing full commercial operations, Sempra Infrastructure capitalized interest of $33 million in 2019 related to this equity method investment. In 2021, 2020 and 2019, Sempra Infrastructure contributed $2 million, $54 million and $77 million, respectively, to Cameron LNG JV. Cameron LNG JV Financing General. In August 2014, Cameron LNG JV entered into finance documents (collectively, Loan Facility Agreements) for senior secured financing in an initial aggregate principal amount of up to $7.4 billion under three debt facilities provided by the Japan Bank for International Cooperation (JBIC) and 29 international commercial banks, some of which will benefit from insurance coverage provided by Nippon Export and Investment Insurance (NEXI). The Loan Facility Agreements and related finance documents provide senior secured term loans with a maturity date of July 15, 2030. The proceeds of the loans were used for financing the cost of development and construction of the three-train Cameron LNG JV project. The Loan Facility Agreements and related finance documents contain customary representations and affirmative and negative covenants for project finance facilities of this kind with the lenders of the type participating in the Cameron LNG JV financing. In December 2019, Cameron LNG JV refinanced the commercial bank portion of the Loan Facility Agreements not covered by NEXI with $3.0 billion of senior secured notes issued in a private placement bond offering. The senior secured notes bear interest at a weighted-average fixed rate of 3.39% at December 31, 2021 with maturity dates ranging between 2031 and 2039. Interest. The weighted-average all-in cost of the loans that remain outstanding under the original Loan Facility Agreements is 0.98% per annum over LIBOR prior to financial completion of the project and 1.22% per annum over LIBOR following financial completion of the project. In November 2014, Cameron LNG JV entered into floating-to-fixed interest rate swaps for approximately $3.7 billion notional amount, resulting in an effective fixed rate of 3.19% for the LIBOR component of the interest rate on the loans. In June 2015, Cameron LNG JV entered into additional floating-to-fixed interest rate swaps effective starting in 2020, for approximately $1.5 billion notional amount, resulting in an effective fixed rate of 3.32% for the LIBOR component of the interest rate on the loans. In December 2019, approximately $790 million of the $1.5 billion notional amount was terminated as a result of the refinancing, resulting in an effective fixed rate of 3.26% for the LIBOR component of the interest rate on the remaining loans outstanding. The weighted-average all-in cost of the loans outstanding under the original Loan Facility Agreements and the newly issued senior secured notes is 3.69%. Guarantees. In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, and Sempra’s guarantees related to agreements entered into in August 2014 and December 2019, for the benefit of all of Cameron LNG JV’s creditors under the original Loan Facility Agreements and the senior secured notes, were terminated. In August 2014, Sempra and the other project owners entered into a transfer restrictions agreement with Société Générale, as intercreditor agent for the lenders under the Loan Facility Agreements. Pursuant to the transfer restriction agreement, starting six months after financial completion of the three-train Cameron LNG JV project, Sempra must retain at least 10% of the indirect fully diluted economic and beneficial ownership interest in Cameron LNG JV. In addition, at all times, a Sempra controlled (but not necessarily wholly owned) subsidiary must directly own 50.2% of the membership interests of Cameron LNG JV. Events of Default. Cameron LNG JV’s Loan Facility Agreements and related finance documents contain events of default customary for such financings, including events of default for: failure to pay principal and interest when due; insolvency of Cameron LNG JV; abandonment of the project; expropriation; and unenforceability or termination of the finance documents. Security. To support Cameron LNG JV’s obligations under its debt agreements, Cameron LNG JV has granted security over all of its assets, subject to customary exceptions, and all equity interests in Cameron LNG JV were pledged to HSBC Bank USA, National Association, as security trustee for the benefit of all of Cameron LNG JV’s creditors. As a result, an enforcement action by the lenders taken in accordance with the finance documents could result in the exercise of such security interests by the lenders and the loss of ownership interests in Cameron LNG JV by Sempra and the other project partners. Sempra Promissory Note for SDSRA Distribution Cameron LNG JV’s debt agreements require Cameron LNG JV to maintain the SDSRA, which is an additional reserve account beyond the Senior Debt Service Accrual Account, where funds accumulate from operations to satisfy senior debt obligations due and payable on the next payment date. Both accounts can be funded with cash or authorized investments. In June 2021, Sempra Infrastructure received a distribution of $165 million based on its proportionate share of the SDSRA, for which Sempra provided a promissory note and letters of credit to secure a proportionate share of Cameron LNG JV’s obligation to fund the SDSRA. Sempra’s maximum exposure to loss is replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $22 million at December 31, 2021, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra Infrastructure’s investment in Cameron LNG JV. The guarantee will terminate upon full repayment of Cameron LNG JV’s debt, scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA. Sempra Support Agreement for CFIN In July 2020, CFIN entered into a financing arrangement with Cameron LNG JV’s four project owners and received aggregate proceeds of $1.5 billion from two project owners and from external lenders on behalf of the other two project owners (collectively, the affiliate loans), based on their proportionate ownership interest in Cameron LNG JV. CFIN used the proceeds from the affiliate loans to provide a loan to Cameron LNG JV. The affiliate loans mature in 2039. Principal and interest will be paid from Cameron LNG JV’s project cash flows from its three-train natural gas liquefaction facility. Cameron LNG JV used the proceeds from its loan to return equity to its project owners. Sempra used its $753 million share of the proceeds for working capital and other general corporate purposes, including the repayment of indebtedness. Sempra Infrastructure’s $753 million proportionate share of the affiliate loans, based on its 50.2% ownership interest in Cameron LNG JV, was funded by external lenders comprised of a syndicate of eight banks (the bank debt) to whom Sempra has provided a guarantee pursuant to a Support Agreement, as amended on June 29, 2021, under which: ▪ Sempra has severally guaranteed repayment of the bank debt plus accrued and unpaid interest if CFIN fails to pay the external lenders; ▪ the external lenders may exercise an option to put the bank debt to Sempra Infrastructure upon the occurrence of certain events, including a failure by CFIN to meet its payment obligations under the bank debt; ▪ the external lenders will put some or all of the bank debt to Sempra Infrastructure on the fifth, tenth, or fifteenth anniversary date of the affiliate loans, except the portion of the debt owed to any external lender that has elected not to participate in the put option six months prior to the respective anniversary date; ▪ Sempra Infrastructure also has a right to call the bank debt back from, or to refinance the bank debt with, the external lenders at any time; and ▪ the Support Agreement will terminate upon full repayment of the bank debt, including repayment following an event in which the bank debt is put to Sempra Infrastructure. In exchange for this guarantee, the external lenders will pay a guarantee fee that is based on the credit rating of Sempra’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra Infrastructure will recognize as interest income as earned. Sempra’s maximum exposure to loss is the bank debt plus any accrued and unpaid interest and related fees, subject to a liability cap of 130% of the bank debt, or $979 million. We measure the Support Agreement at fair value, net of related guarantee fees, on a recurring basis (see Note 12). At December 31, 2021, the fair value of the Support Agreement was $7 million, which is included in Other Current Assets on Sempra’s Consolidated Balance Sheet. ESJ JV As we discuss in Note 5, in March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, Sempra Infrastructure owned 50% of ESJ and accounted for its interest as an equity method investment. IMG JV Sempra Infrastructure has a 40% interest in IMG JV, a JV with a subsidiary of TC Energy Corporation, and accounts for its interest as an equity method investment. IMG JV owns and operates the Sur de Texas-Tuxpan natural gas marine pipeline, which is fully contracted under a 35-year natural gas transportation service contract with the CFE and commenced commercial operations in September 2019. SEMPRA RENEWABLES Sempra Renewables completed the sale of its remaining wind assets and investments in April 2019. We discuss this divestiture further in Note 5. RBS SEMPRA COMMODITIES RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra and RBS in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra. We and RBS sold substantially all of the partnership’s businesses and assets in four separate transactions completed in 2010 and 2011. Since 2011, our investment balance has reflected our share of the remaining partnership assets, including amounts retained by the partnership to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership and the distribution of the partnership’s remaining assets, if any. We account for our investment in RBS Sempra Commodities under the equity method. In 2018, we fully impaired our remaining equity method investment in RBS Sempra Commodities. In 2020, we recorded a charge of $100 million in Equity Earnings on Sempra’s Consolidated Statement of Operations for losses from our investment in RBS Sempra Commodities. In 2021, we reduced this charge by $50 million based on the favorable outcome of a settlement with HMRC and revised assumptions on the High Court of Justice case. We discuss matters related to RBS Sempra Commodities further in “Other Litigation” in Note 16. SUMMARIZED FINANCIAL INFORMATION We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings and RBS Sempra Commodities) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2021 (1) 2020 2019 (2) Gross revenues $ 2,721 $ 2,341 $ 798 Operating expense (719) (706) (372) Income from operations 2,002 1,635 426 Interest expense (548) (514) (401) Net income/Earnings (3) 1,388 1,132 85 At December 31, 2021 (1) 2020 2019 (2) Current assets $ 788 $ 1,035 $ 1,124 Noncurrent assets 14,686 15,304 15,039 Current liabilities 1,230 1,342 1,232 Noncurrent liabilities 11,807 12,863 11,438 (1) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. (2) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments. As of April 22, 2019, these wind assets and investments are no longer equity method investments. (3) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES SHORT-TERM DEBT Committed Lines of Credit At December 31, 2021, Sempra had an aggregate capacity of $9.5 billion under seven primary committed lines of credit, which provide liquidity and support our commercial paper programs. Because our commercial paper programs are supported by these lines of credit, we reflect the amount of commercial paper outstanding, before reductions of any unamortized discounts, and any letters of credit outstanding as a reduction to the available unused credit capacity. COMMITTED LINES OF CREDIT (Dollars in millions) At December 31, 2021 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Available unused credit Sempra May 2024 $ 3,185 $ (1,240) $ — 1,945 Sempra May 2024 1,250 — — 1,250 SDG&E May 2024 1,500 (401) — 1,099 SoCalGas May 2024 750 (385) — 365 SI Partners November 2024 1,000 — — 1,000 IEnova September 2023 350 — (350) — IEnova February 2024 1,500 — (399) 1,101 Total $ 9,535 $ (2,026) $ (749) $ 6,760 The principal terms of the Sempra, SDG&E and SoCalGas primary committed lines of credit reflected in the table above include the following: ▪ Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in any facility. ▪ Sempra’s $1.3 billion facility and SDG&E’s and SoCalGas’ facilities provide for the issuance of $200 million, $100 million and $100 million, respectively, of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra, SDG&E and SoCalGas each have the right to increase its letter of credit commitment up to $500 million, $250 million and $250 million, respectively. ▪ Borrowings bear interest at a benchmark rate plus a margin that varies with the borrower’s credit rating. ▪ Each borrower must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At December 31, 2021, each entity was in compliance with this ratio under its respective credit facility. In November 2021, SI Partners entered into a three-year $1.0 billion credit facility. The principal terms of the SI Partners’ line of credit reflected in the table above include the following: ▪ A syndication of 12 lenders each having an 8.33% share in the facility. ▪ The facility provides for issuance of $200 million of letters of credit. ▪ The facility includes a $100 million swingline loan sub-limit, whereby any outstanding amounts would reduce available unused credit. No swingline loan borrowings were outstanding at December 31, 2021. ▪ Borrowings are issued in U.S. dollars and letters of credit can be issued in U.S. dollars or Mexican pesos. ▪ Borrowings bear interest at a benchmark rate plus a margin that varies with SI Partners’ credit rating. ▪ SI Partners must maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in its credit facility) of no more than 5.25 to 1.00 as of the end of each quarter. At December 31, 2021, SI Partners was in compliance with this ratio. IEnova has two revolving credit facilities. The principal terms of IEnova’s lines of credit reflected in the table above include the following: ▪ The $350 million revolving credit facility, which was amended in September 2021 to increase the amount available under the facility from $280 million to $350 million and extend the expiration date from September 2021 to September 2023, has a single lender and borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps. ▪ The $1.5 billion revolving credit facility has a syndicate of 10 lenders and borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 80 bps. ▪ Borrowings can be issued in U.S. dollars only. Uncommitted Lines of Credit In addition to our committed lines of credit, Sempra Infrastructure’s foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $470 million at December 31, 2021, which are generally used for working capital requirements. We reflect amounts outstanding before reductions of any unamortized discounts. FOREIGN UNCOMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2021 Borrower Expiration date of facility Borrowing denomination Total facility Amounts outstanding Available unused credit IEnova (1) September 2022 U.S. dollars $ 250 $ (250) $ — ECA LNG Phase 1 (2) August 2023 U.S. dollars or Mexican pesos 100 (63) 37 IEnova (3) October 2023 U.S. dollars 100 (8) 92 IEnova (4) October 2023 U.S. dollars or Mexican pesos 20 — 20 Total $ 470 $ (321) $ 149 (1) Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps. (2) Outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps. (3) Borrowings bear interest at a per annum rate equal to between 1-month and 6-month LIBOR plus 52 bps. (4) Borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing. Uncommitted Letters of Credit Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At December 31, 2021, there was approximately $682 million in standby letters of credit outstanding under these agreements. UNCOMMITTED LETTERS OF CREDIT (Dollars in millions) December 31, 2021 Expiration date range Uncommitted letters of credit outstanding SDG&E January 2022 to May 2022 $ 15 SoCalGas March 2022 to November 2022 15 Sempra Infrastructure March 2022 to October 2043 473 Parent and other April 2022 to May 2023 179 Total $ 682 Term Loan In June 2021, SDG&E entered into a $375 million, 364-day term loan with a maturity date of June 27, 2022. At December 31, 2021, $375 million, net of negligible issuance costs, was outstanding under the term loan. The borrowing bears interest at benchmark rates plus 62.5 bps. The term loan provides SDG&E with additional liquidity outside of its line of credit. Weighted-Average Interest Rates The weighted-average interest rates on the total short-term debt at December 31 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2021 2020 2019 Sempra 0.60 % 0.83 % 2.31 % SDG&E 0.65 — 1.97 SoCalGas 0.21 0.14 1.86 LONG-TERM DEBT The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2021 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ — $ 350 $ 350 1.914% payable 2015 through February 2022 17 53 89 3.6% September 1, 2023 450 450 450 2.5% May 15, 2026 500 500 500 6% June 1, 2026 250 250 250 1.7% October 1, 2030 800 800 — 5.875% January and February 2034 (1) — — 176 5.35% May 15, 2035 250 250 250 6.125% September 15, 2037 250 250 250 4% May 1, 2039 (1) — — 75 6% June 1, 2039 300 300 300 5.35% May 15, 2040 250 250 250 4.5% August 15, 2040 500 500 500 3.95% November 15, 2041 250 250 250 4.3% April 1, 2042 250 250 250 3.75% June 1, 2047 400 400 400 4.15% May 15, 2048 400 400 400 4.1% June 15, 2049 400 400 400 3.32% April 15, 2050 400 400 — 2.95% August 15, 2051 750 — — 6,417 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) — 200 — Finance lease obligations: Purchased-power contracts 1,217 1,237 1,255 Other 57 39 15 1,274 1,476 1,270 7,691 7,529 6,410 Current portion of long-term debt (49) (611) (56) Unamortized discount on long-term debt (17) (13) (12) Unamortized debt issuance costs (44) (39) (36) Total SDG&E 7,581 6,866 6,306 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ 500 $ 500 $ 500 3.2% June 15, 2025 350 350 350 2.6% June 15, 2026 500 500 500 2.55% February 1, 2030 650 650 — 5.75% November 15, 2035 250 250 250 5.125% November 15, 2040 300 300 300 3.75% September 15, 2042 350 350 350 4.45% March 15, 2044 250 250 250 4.125% June 1, 2048 400 400 400 4.3% January 15, 2049 550 550 550 3.95% February 15, 2050 350 350 350 4,450 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.55% at December 31, 2021) September 14, 2023 (1) 300 300 — 1.875% Notes May 14, 2026 (1) 4 4 4 5.67% Notes January 18, 2028 (2) 5 5 5 Finance lease obligations 61 54 19 370 363 28 4,820 4,813 3,828 Current portion of long-term debt (11) (10) (6) Unamortized discount on long-term debt (7) (8) (7) Unamortized debt issuance costs (29) (32) (27) Total SoCalGas 4,773 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2021 2020 2019 Sempra: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 Sempra Infrastructure: Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 189 197 207 Loan at variable rates (2.93% at December 31, 2021) December 9, 2025 341 17 — Notes at 2.87% to 3.51% October 1, 2026 (1) — — 22 Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets (2) 154 196 237 3.75% Notes January 14, 2028 300 300 300 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — — 11 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets — 398 423 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 200 2.9% Loan November 15, 2034 (1) 241 241 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 100 — 4.875% Notes January 14, 2048 540 540 540 4.75% Notes January 15, 2051 800 800 — 8,923 11,247 12,298 Current portion of long-term debt (46) (919) (1,464) Unamortized discount on long-term debt (65) (55) (35) Unamortized debt issuance costs (98) (121) (108) Total other Sempra 8,714 10,152 10,691 Total Sempra $ 21,068 $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Total 2022 $ 17 $ — $ 46 $ 63 2023 450 300 257 1,007 2024 — 500 48 548 2025 — 350 410 760 2026 750 500 74 1,324 Thereafter 5,200 3,109 8,088 16,397 Total $ 6,417 $ 4,759 $ 8,923 $ 20,099 (1) Excludes finance lease obligations, discounts, and debt issuance costs. Various long-term obligations totaling $9.1 billion at Sempra at December 31, 2021 are unsecured. This includes unsecured long-term obligations totaling $309 million at SoCalGas. SDG&E does not have unsecured long-term obligations at December 31, 2021. Callable Long-Term Debt At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2021 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ — $ 304 $ 2,299 $ 2,603 Subject to make-whole provisions 6,417 4,450 6,470 17,337 First Mortgage Bonds SDG&E and SoCalGas issue first mortgage bonds secured by liens on their respective utility plant assets. SDG&E and SoCalGas may issue additional first mortgage bonds if in compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of additional first mortgage bonds of $7.3 billion at SDG&E and $1.9 billion at SoCalGas at December 31, 2021. SDG&E In August 2021, SDG&E issued $750 million of 2.95% green first mortgage bonds maturing in 2051 and received proceeds of $737 million, net of debt discount, underwriting discounts and debt issuance costs of $13 million. SDG&E intends to use the net proceeds to finance or refinance eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation. Other Long-Term Debt Sempra In December 2021, Sempra redeemed, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon the early redemptions, we recognized $126 million ($92 million after tax) in charges associated with the make-whole premiums and a write-off of unamortized discount and debt issuance costs. In November 2021, we issued $1.0 billion of 4.125% fixed-to-fixed reset rate junior subordinated notes maturing on April 1, 2052. Interest on the notes accrues from and including November 19, 2021 and is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on April 1, 2022. The notes will bear interest (i) from and including November 19, 2021 to, but excluding, April 1, 2027 at the rate of 4.125% per annum and (ii) from and including April 1, 2027, during each subsequent five-year period beginning on April 1 of every fifth year, at a rate per annum equal to the Five-year U.S. Treasury Rate (as defined in the notes) as of the day falling two business days before the first day of such five-year period plus a spread of 2.868%, to be reset on April 1 of every fifth year beginning in 2027. We received proceeds of $988 million (net of underwriting discounts and debt issuance costs of $12 million). We used the proceeds from the offering to repay a portion of the aggregate principal amount of the $2.35 billion of senior unsecured notes that we discuss above. We may redeem some or all of the notes before their maturity, as follows: ▪ in whole or from time to time in part, on any day during any period from and including the January 1 immediately preceding an interest rate reset date through and including such reset date at a redemption price in cash equal to 100% of the principal amount of the notes to be redeemed, plus accrued and unpaid interest on the notes to be redeemed to, but excluding, the redemption date; ▪ in whole but not in part, at any time following the occurrence and during the continuance of a tax event (as defined in the notes) at a redemption price in cash equal to 100% of the principal amount of the notes, plus accrued and unpaid interest on the notes to, but excluding, the redemption date; and ▪ in whole but not in part, at any time following the occurrence and during the continuance of a rating agency event (as defined in the notes) at a redemption price in cash equal to 102% of the principal amount of the notes, plus accrued and unpaid interest on the notes to, but excluding, the redemption date. The notes are unsecured obligations and rank junior and subordinate in right of payment to our existing and future senior indebtedness. The notes rank equally in right of payment with our existing 5.75% junior subordinated notes due 2079 and with any future unsecured indebtedness that we may incur if the terms of such indebtedness provide that it ranks equally with the notes in right of payment. The notes are effectively subordinated in right of payment to any secured indebtedness we have incurred or may incur and to all existing and future indebtedness and other liabilities of our subsidiaries. SDG&E On February 18, 2022, SDG&E entered into a $400 million, two-year term loan with a maturity date of February 18, 2024. SDG&E may request up to three borrowings for an aggregate amount of $400 million through May 18, 2022. On February 18, 2022, SDG&E borrowed $200 million. The borrowing bears interest at benchmark rates plus 62.5 bps. The margin is based on SDG&E’s long-term senior unsecured credit rating. Sempra Infrastructure SI Partners. On January 11, 2022, SI Partners completed a private offering of $400 million in aggregate principal of 3.25% senior notes due January 15, 2032 to “qualified institutional buyers” as defined in Rule 144A under the Securities Act of 1933, as amended (the Securities Act), and non-U.S. persons outside the U.S. under Regulation S under the Securities Act. The notes were issued at 98.903% of the principal amount and require semi-annual interest payments in January and July, commencing July 15, 2022. The notes are senior unsecured obligations that rank equally with all of SI Partners’ existing and future outstanding unsecured senior indebtedness. Sempra Infrastructure received proceeds of $390 million (net of debt discount, underwriting discounts and debt issuance costs of $10 million). Sempra Infrastructure intends to use the net proceeds for general corporate purposes, which may include the repayment of certain indebtedness of its subsidiaries. At any time prior to October 15, 2031, SI Partners may redeem some or all of the notes by paying the greater of (i) 100% of the principal amount of the notes to be redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest thereon (exclusive of interest accrued to, but excluding, the date of redemption) as if redeemed on October 15, 2031 discounted to the redemption date on a semi-annual basis at the U.S. Treasury rate plus 25 bps and, in each case, accrued and unpaid interest to, but excluding, the date of redemption. At any time beginning on October 15, 2031, SI Partners may redeem some or all of the notes by paying 100% of the principal amount of the notes to be redeemed, plus, in each case, accrued and unpaid interest to, but excluding, the date of redemption. Upon the occurrence of specific kinds of change of control events that result in a downgrade of SI Partners’ credit ratings, holders of the notes would have the right to require SI Partners to offer to purchase some or all of the notes at 101% of the then outstanding principal amount thereof, plus, in each case, accrued and unpaid interest to, but excluding, the date of redemption. ECA LNG Phase 1. In December 2020, ECA LNG Phase 1 entered into a five-year loan agreement with a syndicate of nine banks for an aggregate principal amount of up to $1.6 billion. Proceeds from the loan are being used to finance the cost of development and construction of a one-train natural gas liquefaction export facility with a name-plate capacity of 3.25 Mtpa and initial offtake capacity of approximately 2.5 Mtpa. The loan matures in December 2025 and bears interest at a weighted-average blended rate of 2.70% plus a benchmark interest rate per annum equal to (a) the LIBOR for such interest period divided by (b) one minus the Eurodollar Reserve Percentage; provided that in no event shall the benchmark at any time be less than 0% per annum. ECA LNG Phase 1 may elect for each calendar quarter (i) three successive interest periods of one month or (ii) a single interest period of three months. Sempra and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest based on their proportionate ownership interest in ECA LNG Phase 1 of 83.4% and 16.6%, respectively. The effective interest rate of the loan is based on the interest payments made to external lenders and guarantee payments made to TotalEnergies SE as a guarantor. At December 31, 2021 and 2020, $341 million and $17 million, respectively, was outstanding under the loan agreement, with a weighted-average interest rate of 2.93% and 2.82%, respectively. ESJ. As we discuss in Note 5, through its acquisition of the remaining 50% of ESJ, Sempra Infrastructure assumed a $177 million (net of $6 million in unamortized debt issuance costs) variable rate loan payable to a syndicate of five lenders that matures in June 2033. To moderate exposure to interest rate and associated cash flow variability, ESJ entered into floating-to-fixed rate swaps for 90% of the principal balance, resulting in a fixed rate of 6.13%. The remaining 10% of the principal balance bore interest at 6-month LIBOR plus a margin of 2.63% with an increase of 25 bps every four years. On October 8, 2021, Sempra Infrastructure used proceeds from borrowings against IEnova’s committed and uncommitted lines of credit to fully repay the $175 million of outstanding principal plus accrued and unpaid interest on the ESJ loan prior to its scheduled maturity in 2033, and recognized $18 million ($10 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs. Ventika. On October 13, 2021, Sempra Infrastructure used proceeds from borrowings against IEnova’s committed and uncommitted lines of credit to fully repay $375 million of outstanding principal plus accrued and unpaid interest on the Ventika fixed- and variable-rate loans prior to scheduled maturity dates through 2032, and recognized $36 million ($20 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Income tax expense from continuing operations $ 99 $ 249 $ 315 Income from continuing operations before income taxes and equity earnings $ 219 $ 1,489 $ 1,734 Equity earnings, before income tax (1) 614 294 30 Pretax income $ 833 $ 1,783 $ 1,764 Effective income tax rate 12 % 14 % 18 % SDG&E: Income tax expense $ 201 $ 190 $ 171 Income before income taxes $ 1,020 $ 1,014 $ 945 Effective income tax rate 20 % 19 % 18 % SoCalGas: Income tax (benefit) expense $ (310) $ 96 $ 120 (Loss) income before income taxes $ (736) $ 601 $ 762 Effective income tax rate 42 % 16 % 16 % (1) We discuss how we recognize equity earnings in Note 6. For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment: ▪ repairs expenditures related to a certain portion of utility plant fixed assets ▪ the equity portion of AFUDC, which is non-taxable ▪ a portion of the cost of removal of utility plant assets ▪ utility self-developed software expenditures ▪ depreciation on a certain portion of utility plant assets ▪ state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment. We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Through the first quarter of 2021, such effects are offset by net gains (losses) from foreign currency derivatives that were hedging Sempra Infrastructure’s exposure to movements in the Mexican peso from its controlling interest in IEnova. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2021 2020 2019 Sempra: U.S. federal statutory income tax rate 21 % 21 % 21 % Outside basis differences 9 — — Utility depreciation 8 3 3 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (1) 5 2 3 Foreign exchange and inflation effects (2) 1 (3) 4 Valuation allowances 1 (1) — Tax credits — (1) (2) Excess deferred income taxes outside of ratemaking — — (4) Compensation-related items (1) (1) — Impairment losses (1) 1 — Noncontrolling interests (2) — — Allowance for equity funds used during construction (3) (1) (1) Amortization of excess deferred income taxes (3) (1) (1) Remeasurement of deferred taxes (4) — — State income taxes, net of federal income tax benefit (4) 1 2 Utility self-developed software expenditures (5) (3) (2) Utility repairs expenditures (9) (4) (3) Other, net (1) 1 (2) Effective income tax rate 12 % 14 % 18 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 5 5 6 Depreciation 3 3 3 Excess deferred income taxes outside of ratemaking — — (3) Self-developed software expenditures (1) (4) (3) Amortization of excess deferred income taxes (2) (1) (1) Allowance for equity funds used during construction (2) (2) (1) Repairs expenditures (4) (3) (3) Other, net — — (1) Effective income tax rate 20 % 19 % 18 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 11 2 4 Repairs expenditures 5 (7) (4) Self-developed software expenditures 5 (4) (2) Amortization of excess deferred income taxes 2 (1) (1) Allowance for equity funds used during construction 1 (1) (1) Nondeductible expenditures — 2 — Excess deferred income taxes outside of ratemaking — — (5) Depreciation (5) 5 4 Other, net 2 (1) — Effective income tax rate 42 % 16 % 16 % (1) Related to operations in Mexico. (2) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. We also recognize gains (losses) in Other Income (Expense), Net, on the Consolidated Statements of Operations from foreign currency derivatives that are partially hedging Sempra Infrastructure’s exposure to movements in the Mexican peso from its controlling interest in IEnova. In January 2019, our board of directors approved a plan to sell our South American businesses and we completed the sales in the second quarter of 2020, as we discuss in Note 5. Prior to this decision, our repatriation estimate excluded post-2017 earnings and other basis differences related to our South American businesses. Because of our decision to sell our South American businesses, we no longer assert indefinite reinvestment of these basis differences. Accordingly, we recorded the following income tax impacts from changes in outside basis differences in our discontinued operations in South America: ▪ $89 million income tax benefit in 2019 primarily related to outside basis differences existing as of the January 25, 2019 approval of our plan to sell our South American businesses; and ▪ $7 million income tax benefit in 2020 compared to $51 million income tax expense in 2019 related to changes in outside basis differences from earnings and foreign currency effects since January 25, 2019. We expect to repatriate approximately $1.8 billion of foreign undistributed earnings in the foreseeable future, and have accrued $59 million of U.S. state deferred income tax liability at December 31, 2021 for repatriations that we expect will begin in 2022 as cash is generated. We repatriated approximately $4.7 billion and $254 million to the U.S. in 2020 and 2019, respectively. We have not recorded deferred income taxes with respect to remaining basis differences of approximately $600 million between financial statement and income tax investment amounts in our non-U.S. subsidiaries because we consider them to be indefinitely reinvested as of December 31, 2021. However, the sale of NCI in SI Partners to ADIA, which we discuss in Note 1, would affect our indefinite reinvestment assertion. The remaining basis differences are calculated pursuant to U.S. federal tax law, which may differ from tax law in California and foreign jurisdictions. It is currently not practicable to determine the hypothetical amount of tax that might be payable if the underlying basis differences were realized. The remeasurement of deferred income tax balances at SDG&E and SoCalGas in December 2017, as a result of the TCJA, resulted in excess deferred income taxes that previously had been collected from ratepayers at the higher rate. In a January 2019 decision, the CPUC directed certain excess deferred income tax balances generated by activities outside of ratemaking be allocated to shareholders rather than ratepayers. As a result, in 2019, SDG&E and SoCalGas recorded income tax benefits of $31 million and $38 million, respectively, from the release of a portion of the regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances. The table below presents the geographic components of pretax income. PRETAX INCOME (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: By geographic components: U.S. $ 346 $ 1,461 $ 1,191 Non-U.S. 487 322 573 Total (1) $ 833 $ 1,783 $ 1,764 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the calculation of pretax income. U.S. pretax income was lower in 2021 compared to 2020 and 2019 primarily due to the 2021 charges at SoCalGas related to civil litigation pertaining to the Leak, which we describe in Note 16. The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Current: U.S. state $ (6) $ (22) $ (14) Non-U.S. 183 112 140 Total 177 90 126 Deferred: U.S. federal (9) 157 87 U.S. state (37) 36 21 Non-U.S. (31) (34) 84 Total (77) 159 192 Deferred investment tax credits (1) — (3) Total income tax expense $ 99 $ 249 $ 315 SDG&E: Current: U.S. federal $ 35 $ 121 $ 35 U.S. state 13 34 31 Total 48 155 66 Deferred: U.S. federal 99 11 75 U.S. state 54 25 32 Total 153 36 107 Deferred investment tax credits — (1) (2) Total income tax expense $ 201 $ 190 $ 171 SoCalGas: Current: U.S. federal $ 134 $ 163 $ 8 U.S. state 50 45 24 Total 184 208 32 Deferred: U.S. federal (334) (85) 79 U.S. state (159) (28) 10 Total (493) (113) 89 Deferred investment tax credits (1) 1 (1) Total income tax (benefit) expense $ (310) $ 96 $ 120 The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES – SEMPRA (Dollars in millions) December 31, 2021 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 5,230 $ 4,891 $ 4,052 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 47 46 153 Regulatory balancing accounts 538 587 468 Right-of-use assets – operating leases 160 144 131 Property taxes 52 51 44 Other deferred income tax liabilities 50 40 93 Total deferred income tax liabilities 6,077 5,759 4,941 Deferred income tax assets: Tax credits 1,135 1,161 1,136 Net operating losses 706 1,299 911 Postretirement benefits 30 162 200 Compensation-related items 164 169 161 Operating lease liabilities 140 125 131 Other deferred income tax assets 130 97 60 State income taxes 21 20 8 Bad debt allowance 33 35 4 Accrued expenses not yet deductible 575 130 52 Deferred income tax assets before valuation allowances 2,934 3,198 2,663 Less: valuation allowances 183 174 144 Total deferred income tax assets 2,751 3,024 2,519 Net deferred income tax liability (2) $ 3,326 $ 2,735 $ 2,422 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2021, 2020, and 2019, includes $151, $136, and $155, respectively, recorded as a noncurrent asset and $3,477, $2,871, and $2,577, respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES – SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2021 2020 2019 2021 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,970 $ 1,833 $ 1,735 $ 1,444 $ 1,322 $ 1,246 Regulatory balancing accounts 323 224 141 215 362 327 Right-of-use assets – operating leases 52 28 32 16 21 22 Property taxes 35 34 30 17 17 14 Other 1 2 14 1 1 1 Total deferred income tax liabilities 2,381 2,121 1,952 1,693 1,723 1,610 Deferred income tax assets: Tax credits 5 5 6 3 3 3 Postretirement benefits — 14 37 18 123 120 Compensation-related items 12 12 6 33 36 25 Operating lease liabilities 52 28 32 16 21 22 Bad debt allowance 16 18 3 15 15 1 State income taxes 4 8 7 12 11 8 Accrued expenses not yet deductible 16 14 9 539 93 15 Other 1 3 4 18 15 13 Total deferred income tax assets 106 102 104 654 317 207 Net deferred income tax liability $ 2,275 $ 2,019 $ 1,848 $ 1,039 $ 1,406 $ 1,403 The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2021 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,263 Indefinite General business tax credits (1) 436 2032 Foreign tax credits (2) 688 2024 U.S. state (2) : NOLs 2,938 2022 General business tax credits 6 2022 Non-U.S. (2) – NOLs 248 2022 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred income tax asset in the future. Of the valuation allowances recorded to date, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses in various U.S. state and non-U.S. jurisdictions resulting in deferred income tax assets that we currently do not believe will be realized on a more-likely-than-not basis. The following table provides the valuation allowances that we recorded against a portion of our total deferred income tax assets shown above in the “Deferred Income Taxes – Sempra” table. VALUATION ALLOWANCES (Dollars in millions) December 31, 2021 2020 2019 Sempra: U.S. federal $ 128 $ 118 $ 90 U.S. state 31 32 33 Non-U.S. 24 24 21 $ 183 $ 174 $ 144 Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2021 2020 2019 Sempra: Balance at January 1 $ 99 $ 93 $ 119 Increase in prior period tax positions 3 3 5 Decrease in prior period tax positions (2) (1) — Increase in current period tax positions 204 4 2 Settlements with taxing authorities — — (32) Expiration of statutes of limitations — — (1) Balance at December 31 $ 304 $ 99 $ 93 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (105) $ (87) $ (81) increase the effective tax rate (1) 34 31 27 SDG&E: Balance at January 1 $ 13 $ 12 $ 11 Increase in prior period tax positions 1 1 1 Balance at December 31 $ 14 $ 13 $ 12 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (11) $ (10) $ (9) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 68 $ 64 $ 61 Increase in prior period tax positions 1 1 1 Increase in current period tax positions 3 3 2 Balance at December 31 $ 72 $ 68 $ 64 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (63) $ (59) $ (55) increase the effective tax rate (1) 33 30 26 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2021 2020 2019 Sempra: Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities $ 8 $ 8 $ 8 SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 6 $ 6 $ 6 SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 2 $ 2 $ 2 Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in Income Tax Expense on the Consolidated Statements of Operations. Sempra accrued negligible amounts at December 31, 2021 and 2020 and $1 million for interest expense and penalties at December 31, 2019 on the Consolidated Balance Sheets, and recorded negligible amounts for interest and penalties in the Consolidated Statements of Operations for all periods presented. SDG&E and SoCalGas each accrued negligible amounts for interest expense and penalties at December 31, 2021, 2020, and 2019 on the Consolidated Balance Sheets, and recorded negligible amounts of interest expense and penalties in the Consolidated Statements of Operations for all periods presented. INCOME TAX AUDITS Sempra is subject to U.S. federal income tax as well as income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2017. We are subject to examination by major state tax jurisdictions for tax years after 2012. Certain major non-U.S. income tax returns for tax years 2013 through the present are open to examination. We are also open to examination for non-U.S. income tax returns related to our prior interest in our commodities business, which we divested in 2010, for years 2009 and 2010. SDG&E and SoCalGas are subject to U.S. federal income tax and state income tax. They remain subject to examination for U.S. federal tax years after 2017 and state tax years after 2012. In addition, Sempra has filed protests to contest proposed state audit adjustments for tax years 2009 through 2012. The pre-2013 tax years for our major state tax jurisdictions are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these tax years.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Employee Benefit Plans	EMPLOYEE BENEFIT PLANS For our employee benefit plans, we: ▪ recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the balance sheet; ▪ measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year; and ▪ recognize changes in the funded status of pension and PBOP plans in the year in which the changes occur. Generally, those changes are reported in OCI and as a separate component of shareholders’ equity. The detailed information presented below covers the employee benefit plans of primarily Sempra and its consolidated subsidiaries. Sempra has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas, which collectively cover all eligible employees, including a member of the Sempra board of directors who was a participant in a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology. IEnova has an unfunded noncontributory defined benefit plan covering all employees that provides defined benefits to retirees based on date of hire, years of service and final average earnings. Sempra also has PBOP plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits. Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. We review these assumptions on an annual basis and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. RABBI TRUST In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $567 million, $512 million and $488 million at December 31, 2021, 2020 and 2019, respectively. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS Benefit Plan Amendments Affecting 2019 In 2019, certain executive participants in a company nonqualified pension plan became eligible in this same plan for Supplemental Executive Retirement Plan benefits. This was treated as a plan amendment and increased the recorded pension liability by $5 million at Sempra, $3 million at SDG&E and $2 million at SoCalGas in 2019. Oncor In 2021, 2020 and 2019, we had $7 million, $11 million and $27 million, respectively, in AOCI representing an actuarial loss related to Oncor’s pension plans. Benefit Obligations and Assets The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2021, 2020 and 2019, and a statement of the funded status at December 31, 2021, 2020 and 2019: PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 4,077 $ 3,768 $ 3,339 $ 989 $ 913 $ 868 Service cost 145 129 110 23 18 17 Interest cost 112 129 139 28 33 36 Contributions from plan participants — — — 21 22 21 Actuarial (gain) loss (76) 351 445 (53) 79 45 Plan amendments — — 5 — — — Benefit payments (98) (93) (93) (68) (74) (72) Settlements (303) (207) (177) — (2) (2) Net obligation at December 31 3,857 4,077 3,768 940 989 913 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 3,002 2,662 2,160 1,399 1,281 1,108 Actual return on plan assets 340 350 496 51 164 218 Employer contributions 241 290 276 5 8 8 Contributions from plan participants — — — 21 22 21 Benefit payments (98) (93) (93) (68) (74) (72) Settlements (303) (207) (177) — (2) (2) Fair value of plan assets at December 31 3,182 3,002 2,662 1,408 1,399 1,281 Funded status at December 31 $ (675) $ (1,075) (1,106) $ 468 $ 410 $ 368 Net recorded (liability) asset at December 31 $ (675) $ (1,075) (1,106) $ 468 $ 410 $ 368 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SDG&E: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 913 $ 895 $ 814 $ 193 $ 177 $ 170 Service cost 35 31 30 5 4 4 Interest cost 25 30 34 5 6 7 Contributions from plan participants — — — 7 8 7 Actuarial (gain) loss (2) 37 61 (3) 17 7 Plan amendments — — 3 — — — Benefit payments (17) (18) (18) (19) (20) (18) Settlements (69) (52) (39) — — — Transfer of liability from other plans — (10) 10 — 1 — Net obligation at December 31 885 913 895 188 193 177 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 819 739 600 213 197 172 Actual return on plan assets 73 94 135 (5) 26 36 Employer contributions 53 52 52 1 1 — Contributions from plan participants — — — 7 8 7 Benefit payments (17) (18) (18) (19) (20) (18) Settlements (69) (52) (39) — — — Transfer of assets from other plans — 4 9 — 1 — Fair value of plan assets at December 31 859 819 739 197 213 197 Funded status at December 31 $ (26) $ (94) (156) $ 9 $ 20 $ 20 Net recorded (liability) asset at December 31 $ (26) $ (94) (156) $ 9 $ 20 $ 20 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits (Dollars in millions) 2021 2020 2019 2021 2020 2019 SoCalGas: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,829 $ 2,526 $ 2,148 $ 749 $ 688 $ 646 Service cost 97 86 68 17 14 12 Interest cost 78 88 91 22 25 27 Contributions from plan participants — — — 13 14 13 Actuarial (gain) loss (83) 282 345 (49) 57 39 Plan amendments — — 2 — — — Benefit payments (63) (60) (59) (46) (49) (49) Settlements (211) (105) (65) — — — Transfer of liability to other plans — 12 (4) — — — Net obligation at December 31 2,647 2,829 2,526 706 749 688 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,969 1,737 1,385 1,159 1,059 916 Actual return on plan assets 243 243 320 51 134 178 Employer contributions 157 152 152 1 1 1 Contributions from plan participants — — — 13 14 13 Benefit payments (63) (60) (59) (46) (49) (49) Settlements (211) (105) (65) — — — Transfer of assets from other plans — 2 4 — — — Fair value of plan assets at December 31 2,095 1,969 1,737 1,178 1,159 1,059 Funded status at December 31 $ (552) $ (860) $ (789) $ 472 $ 410 $ 371 Net recorded (liability) asset at December 31 $ (552) $ (860) $ (789) $ 472 $ 410 $ 371 Actuarial losses (gains) fluctuate based on changes in assumptions that we describe below in “Assumptions for Pension and Other Postretirement Benefit Plans” and updates to census data. In 2021, 2020 and 2019, the Society of Actuaries released updated mortality improvement projection scales, reflecting changes to projected observed longevity improvements in its mortality tables. We have incorporated these assumptions, adjusted for the Sempra companies’ actual mortality experience, in our calculations for each of those years. ▪ Actuarial gains in pension plans at Sempra in 2021 were driven primarily by an increase in discount rates at SoCalGas, SDG&E and Sempra and updated census data at SoCalGas. These actuarial gains were partially offset by actuarial losses at SDG&E, SoCalGas and Sempra due to an increase in the interest crediting rate for the cash balance plans, at SDG&E and Sempra due to updated census data and at SoCalGas due to a decrease in the conversion rate used to determine lump-sum distributions. ▪ Actuarial gains in PBOP plans at Sempra in 2021 were driven primarily by an increase in discount rates at SoCalGas, SDG&E and Sempra, updated census data at SoCalGas and a reduction in the 2022 expected health care costs at SoCalGas. Net Assets and Liabilities The assets and liabilities of the pension and PBOP plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Our funded pension and PBOP plans use the asset smoothing method, except for those at SDG&E. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic benefit cost. SDG&E does not use the asset smoothing method, but rather recognizes realized and unrealized investment gains and losses during the current year. The 10% corridor accounting method is used at Sempra, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The asset smoothing and 10% corridor accounting methods help mitigate volatility of net periodic benefit costs from year to year. Defined benefit pension and other postretirement plans with an aggregated overfunded status are recognized as an asset and with an aggregated underfunded status are recognized as a liability; unrecognized changes in these assets and/or liabilities are normally recorded in AOCI on the balance sheet. SDG&E and SoCalGas record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on decisions by regulatory agencies. SDG&E and SoCalGas record annual pension and other postretirement net periodic benefit costs equal to the contributions to their qualified plans as authorized by the CPUC. The annual contributions to the pension plans are the greater of: ▪ a minimum required funding amount as required by the IRS; ▪ the amount required to maintain an 85% Adjusted Funding Target Attainment Percentage as defined by the Pension Protection Act of 2006, as amended; or ▪ beginning January 1, 2019 and for the duration of the 2019 GRC cycle, a fixed amount equal to the estimated annual service cost as defined by U.S. GAAP plus one year of a 14-year amortization of the unfunded projected benefit obligation of the pension plan as of January 1, 2019, and limited to an annual amount that keeps the fair value of the pension plan assets from exceeding 110% of the pension benefit obligation of the plan. The annual contributions to PBOP plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with U.S. GAAP for pension and PBOP plans. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for SDG&E and SoCalGas are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. The net (liability) asset is included in the following categories on the Consolidated Balance Sheets at December 31: PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Noncurrent assets $ 19 $ — $ — $ 481 $ 430 $ 391 Current liabilities (19) (35) (59) (1) (1) (3) Noncurrent liabilities (675) (1,040) (1,047) (12) (19) (20) Net recorded (liability) asset $ (675) $ (1,075) $ (1,106) $ 468 $ 410 $ 368 SDG&E: Noncurrent assets $ — $ — $ — $ 9 $ 20 $ 20 Current liabilities (1) (2) (3) — — — Noncurrent liabilities (25) (92) (153) — — — Net recorded (liability) asset $ (26) $ (94) $ (156) $ 9 $ 20 $ 20 SoCalGas: Noncurrent assets $ — $ — $ — $ 472 $ 410 $ 371 Current liabilities (1) (7) (4) — — — Noncurrent liabilities (551) (853) (785) — — — Net recorded (liability) asset $ (552) $ (860) $ (789) $ 472 $ 410 $ 371 Amounts recorded in AOCI at December 31, net of income tax effects and amounts recorded as regulatory assets, are as follows: AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra (1) : Net actuarial (loss) gain $ (86) $ (102) $ (113) $ 11 $ 8 $ 10 Prior service cost (8) (11) (14) — — — Total $ (94) $ (113) $ (127) $ 11 $ 8 $ 10 SDG&E: Net actuarial loss $ (9) $ (8) $ (9) Prior service cost (1) (2) (7) Total $ (10) $ (10) $ (16) SoCalGas: Net actuarial loss $ (15) $ (14) $ (7) Prior service cost (3) (4) (3) Total $ (18) $ (18) $ (10) (1) Includes discontinued operations in 2020 and 2019. Sempra, SDG&E and SoCalGas each have a funded pension plan. The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2021 2020 2019 Sempra: Projected benefit obligation $ 2,612 $ 3,679 $ 3,578 Accumulated benefit obligation 2,277 3,265 3,229 Fair value of plan assets 2,095 2,788 2,662 SDG&E: Projected benefit obligation $ 887 $ 861 Accumulated benefit obligation 834 818 Fair value of plan assets 819 739 SoCalGas: Projected benefit obligation $ 2,612 $ 2,792 $ 2,505 Accumulated benefit obligation 2,277 2,431 2,208 Fair value of plan assets 2,095 1,969 1,737 We also have unfunded pension plans at Sempra, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans at December 31: OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) 2021 2020 2019 Sempra: Projected benefit obligation $ 178 $ 184 $ 190 Accumulated benefit obligation 139 146 158 SDG&E: Projected benefit obligation $ 26 $ 26 $ 34 Accumulated benefit obligation 22 22 27 SoCalGas: Projected benefit obligation $ 35 $ 37 $ 21 Accumulated benefit obligation 29 31 17 Sempra, SDG&E and SoCalGas each have a funded other postretirement benefit plan. At December 31, 2021, the assets for SDG&E’s and SoCalGas’ other postretirement benefit plans exceeded the plans’ obligations. The following table shows the obligations of funded other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2021 2020 2019 Sempra: Accumulated postretirement benefit obligation $ 34 $ 33 $ 32 Fair value of plan assets 33 27 25 We also have unfunded other postretirement benefit plans at Sempra. The following table shows the obligations of unfunded other postretirement benefit plans at December 31: OBLIGATIONS OF UNFUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2021 2020 2019 Sempra: Accumulated postretirement benefit obligation $ 12 $ 14 $ 16 Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost and pretax amounts recognized in OCI for the years ended December 31: NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: NET PERIODIC BENEFIT COST Service cost $ 145 $ 129 $ 110 $ 23 $ 18 $ 17 Interest cost 112 129 139 28 33 36 Expected return on assets (173) (169) (144) (61) (55) (71) Amortization of: Prior service cost (credit) 11 12 12 (2) (2) — Actuarial loss (gain) 45 35 36 (9) (10) (10) Settlement charges 38 22 28 — — — Net periodic benefit cost (credit) 178 158 181 (21) (16) (28) Regulatory adjustment 57 91 77 21 16 29 Total expense recognized 235 249 258 — — 1 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net (gain) loss (5) 28 17 (4) 1 (3) Prior service cost — — 5 — — — Amortization of actuarial loss (8) (14) (13) — — — Amortization of prior service cost (4) (4) (3) — — — Settlements (7) (22) (28) — — — Total recognized in OCI (24) (12) (22) (4) 1 (3) Total recognized in net periodic benefit cost and OCI $ 211 $ 237 $ 236 $ (4) $ 1 $ (2) (1) Includes discontinued operations in 2020 and 2019. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SDG&E: NET PERIODIC BENEFIT COST Service cost $ 35 $ 31 $ 30 $ 5 $ 4 $ 4 Interest cost 25 30 34 5 6 7 Expected return on assets (50) (49) (38) (10) (10) (11) Amortization of: Prior service cost 1 2 3 — — 2 Actuarial loss (gain) 2 3 11 (2) (3) (2) Settlement charges 6 — — — — — Net periodic benefit cost (credit) 19 17 40 (2) (3) — Regulatory adjustment 34 38 14 2 3 — Total expense recognized 53 55 54 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 1 6 5 — — — Prior service cost — — 2 — — — Transfer of actuarial gain — (7) — — — — Transfer of prior service credit — (5) — — — — Amortization of actuarial loss — (1) — — — — Amortization of prior service cost (1) (1) (1) — — — Total recognized in OCI — (8) 6 — — — Total recognized in net periodic benefit cost and OCI $ 53 $ 47 $ 60 $ — $ — $ — NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SoCalGas: NET PERIODIC BENEFIT COST Service cost $ 97 $ 86 $ 68 $ 17 $ 14 $ 12 Interest cost 78 88 91 22 25 27 Expected return on assets (113) (107) (94) (48) (43) (58) Amortization of: Prior service cost (credit) 8 8 8 (3) (2) (2) Actuarial loss (gain) 36 26 16 (7) (7) (8) Settlement charges 25 — — — — — Net periodic benefit cost (credit) 131 101 89 (19) (13) (29) Regulatory adjustment 23 53 63 19 13 29 Total expense recognized 154 154 152 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 2 6 2 — — — Prior service cost — — 3 — — — Transfer of actuarial loss (gain) — 5 (4) — — — Transfer of prior service cost (credit) — 3 (1) — — — Amortization of actuarial loss (1) (1) (1) — — — Amortization of prior service cost (1) (1) — — — — Total recognized in OCI — 12 (1) — — — Total recognized in net periodic benefit cost and OCI $ 154 $ 166 $ 151 $ — $ — $ — Assumptions for Pension and Other Postretirement Benefit Plans Benefit Obligation and Net Periodic Benefit Cost Except for the IEnova plans, we develop the discount rate assumptions using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flows to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of corporate bonds with a Bloomberg Composite of AA or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plans’ projected benefit payments discounted at this rate with the market value of the bonds selected. We develop the discount rate assumptions for the plans at IEnova by constructing a synthetic government zero coupon bond yield curve from the available market data, based on duration matching, and we add a risk spread to allow for the yields of high-quality corporate bonds. Such method is required when there is no deep market for high quality corporate bonds. Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types. Interest crediting rate is based on an average 30-year Treasury bond from the month of November of the preceding year. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under U.S. GAAP. The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Discount rate 3.04 % 2.78 % 3.49 % 3.04 % 2.88 % 3.54 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 2.99 % 2.73 % 3.44 % 3.05 % 2.85 % 3.55 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 1.62 2.28 Rate of compensation increase 3.50-10.00 2.70-10.00 2.70-10.00 3.50-10.00 2.70-10.00 2.70-10.00 SoCalGas: Discount rate 3.04 % 2.79 % 3.50 % 3.05 % 2.90 % 3.55 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 % 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Discount rate 2.78 % 3.49 % 4.29 % 2.88 % 3.54 % 4.29 % Expected return on plan assets 6.47 7.00 7.00 4.76 4.64 6.48 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 SDG&E: Discount rate 2.73 % 3.44 % 4.29 % 2.85 % 3.55 % 4.30 % Expected return on plan assets 6.25 7.00 7.00 4.81 5.51 6.92 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 SoCalGas: Discount rate 2.79 % 3.50 % 4.30 % 2.90 % 3.55 % 4.30 % Expected return on plan assets 6.75 7.00 7.00 4.70 4.41 6.38 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. Health Care Cost Trend Rates Assumed health care cost trend rates have a significant effect on the amounts that Sempra, SDG&E and SoCalGas report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans: ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2021 2020 2019 2021 2020 2019 Health care cost trend rate assumed for next year 6.00 % 6.00 % 6.25 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 2022 2022 2022 Plan Assets Investment Allocation Strategy for Sempra’s Pension Master Trust Sempra’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. We maintain additional trusts, as we discuss below, for certain of SDGE’s and SoCalGas’ PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks. Currently, the pension plans’ target asset allocations are: ▪ 31% domestic equity ▪ 21% international equity ▪ 21% long credit ▪ 10% diversified real assets ▪ 10% return-seeking credit ▪ 5% ultra-long duration government securities ▪ 2% other diversifying assets The asset allocation of the plans is reviewed by our Plan Funding Committee and our Pension and Benefits Investment Committee (the Committees) on a regular basis. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪ long-term cost ▪ variability and level of contributions ▪ funded status ▪ a range of expected outcomes over varying confidence levels This allocation results in a 74% target allocation to return-seeking assets and a 26% target allocation to risk-mitigating assets. We maintain asset allocations at strategic levels with reasonable bands of variance. In accordance with the Sempra pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on assets in our pension and PBOP plans is based on the weighted-average of the plans’ investment allocations to specific asset classes as of the measurement date. We arrive at a 6.75% expected return on assets by considering both the historical and forecasted long-term rates of return on those asset classes. We expect a return of between 4% and 12% on return-seeking assets and between 1% and 4% for risk-mitigating assets. Certain trusts that hold assets for the SDG&E other postretirement benefit plan are subject to taxation, which impacts the expected after-tax return on assets in the plan. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. Investment Strategy for SDG&E’s and SoCalGas’ Other Postretirement Benefit Plans SDG&E’s and SoCalGas’ PBOP plans are funded by cash contributions from SDG&E and SoCalGas and their current retirees. The assets of these plans are placed into the pension master trust and other Voluntary Employee Beneficiary Association trusts. Certain assets of SDG&E’s and SoCalGas’ PBOP plans are held in the pension master trust, which invests a portion of the assets in completion portfolios that aim to reduce interest rate risk, thereby resulting in an overall target allocation of 38% to return-seeking assets and 62% to risk-mitigating assets for these well-funded plans. Certain of SoCalGas’ PBOP plans are held in a Voluntary Employee Benefit Association trust that also utilizes a completion portfolio, resulting in a target allocation of 30% to return-seeking assets and 70% to risk-mitigating assets. SDG&E’s and SoCalGas’ assets held in other Voluntary Employee Beneficiary Association trusts are invested in accordance with a de-risking glidepath that reduces the assets’ exposure to risk as the trusts become better funded. These specific allocations are periodically reviewed to help ensure that plan assets are best positioned to meet plan obligations. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in Sempra’s pension master trust and the trusts for SDG&E’s and SoCalGas’ PBOP plans based on the fair value hierarchy, except for certain investments measured at NAV. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and other postretirement benefit plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Registered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices. Where the value is a quoted price in an active market, the investment is classified within Level 1 of the fair value hierarchy. Other investments are valued under a discounted cash flow 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. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flow 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. Certain high yield fixed-income securities are valued by applying a price adjustment to the bid side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Common/Collective Trusts – Investments in common/collective trust funds are valued based on the NAV of units owned, which is based on the current fair value of the funds’ underlying assets. Venture Capital Funds and Real Estate Funds – These funds consist of investments in venture capital funds and real estate funds that are held by limited partnerships or similar private entities following various investment strategies. The value is determined based on the NAV of our proportionate ownership interest in the entity. Derivative Financial Instruments – Futures contracts that are publicly traded in active markets are valued at closing prices as of the last business day of the year. Forward currency contracts are valued at the prevailing forward exchange rate of the underlying currencies, and unrealized gain (loss) is recorded daily. Fixed income futures and options are marked to market daily. Equity index futures contracts are valued at the last sales price quoted on the exchange on which they primarily trade. While management believes the valuation methods described above are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. We provide more discussion of fair value measurements in Notes 1 and 12. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis. SDG&E and SoCalGas each hold a proportionate share of investment assets in the pension master trust at Sempra. The fair values of our pension plan assets by asset category are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Total Sempra: Cash and cash equivalents $ 18 $ — $ 18 Equity securities: Domestic 844 5 849 International 384 1 385 Registered investment companies: Domestic 204 21 225 International 33 — 33 Fixed income securities: Domestic government and government agencies 463 24 487 International government bonds — 11 11 Domestic corporate bonds — 413 413 International corporate bonds — 65 65 Other 1 — 1 Total investment assets in the fair value hierarchy $ 1,947 $ 540 2,487 Accounts receivable/payable, net (20) Investments measured at NAV: Common/collective trusts 657 Venture capital funds and real estate funds 58 Total investment assets $ 3,182 SDG&E’s proportionate share of investment assets $ 859 SoCalGas’ proportionate share of investment assets $ 2,095 Fair value at December 31, 2020 Level 1 Level 2 Total Sempra: Cash and cash equivalents $ 7 $ — $ 7 Equity securities: Domestic 931 — 931 International 563 — 563 Registered investment companies: Domestic 151 37 188 International 32 — 32 Fixed income securities: Domestic government and government agencies 238 34 272 International government bonds — 13 13 Domestic corporate bonds — 418 418 International corporate bonds — 61 61 Other 2 (1) 1 Total investment assets in the fair value hierarchy $ 1,924 $ 562 2,486 Accounts receivable/payable, net 13 Investments measured at NAV: Common/collective trusts 493 Venture capital funds and rea

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Share-based Compensation	SHARE-BASED COMPENSATION SEMPRA EQUITY COMPENSATION PLANS Sempra has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra. The plans permit a wide variety of share-based awards, including: ▪ nonqualified stock options ▪ incentive stock options ▪ restricted stock awards ▪ restricted stock units ▪ stock appreciation rights ▪ performance awards ▪ stock payments ▪ dividend equivalents Eligible employees, including those from SDG&E and SoCalGas, participate in Sempra’s share-based compensation plans as a component of their compensation package. In the three years ended December 31, 2021, Sempra had the following types of equity awards outstanding: ▪ Nonqualified Stock Options : Options to purchase common stock have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a three ▪ Performance-Based Restricted Stock Units : These RSU awards generally vest in Sempra common stock at the end of three ◦ Up to an additional 100% of the granted RSUs may be issued if total return to shareholders or EPS growth exceeds target levels. ◦ For awards granted in 2016 and certain awards granted in 2017 and 2018 that vest based on Sempra’s total return to shareholders, a modifier adds 20% to the award’s payout (as initially calculated based on total return to shareholders relative to that of specified market indices) for total shareholder return performance in the top quartile relative to historical benchmark data for Sempra and reduces the award’s payout by 20% for performance in the bottom quartile. However, in no event will more than an additional 100% of the granted RSUs be issued. If performance falls within the second or third quartiles, the modifier is not triggered, and the payout is based solely on total return to shareholders relative to that of specified market indices. If Sempra’s total return to shareholders or EPS growth is below the target levels but above threshold performance levels, shares are subject to partial vesting on a pro rata basis. ▪ Other Performance-Based Restricted Stock Units: RSUs were granted in 2015 in connection with the creation of Cameron LNG JV. The 2015 awards vested in 2019 as both of the following were achieved: (a) the Compensation and Talent Committee of Sempra’s board of directors determined that Sempra achieved positive cumulative net income for fiscal years 2015 through 2017 and (b) Cameron LNG JV commenced commercial operations of the first train. ▪ Service-Based Restricted Stock Units: RSUs may also be service-based; these generally vest ratably over three three four For awards that would otherwise be forfeited upon termination of employment, the Compensation and Talent Development Committee of Sempra’s board of directors may waive the forfeiture requirement and, with respect to options and service-based RSUs, may accelerate vesting. Awards are also subject to accelerated vesting upon a change in control under the applicable LTIP, in accordance with severance pay agreements or to the extent otherwise required by the terms of the applicable award. Dividend equivalents on shares subject to RSUs are reinvested to purchase additional common shares that become subject to the same vesting conditions as the RSUs to which the dividends relate. SHARE-BASED AWARDS AND COMPENSATION EXPENSE At December 31, 2021, 5,986,241 common shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three four Sempra subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra plans’ corporate staff costs. Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Share-based compensation expense, before income taxes (1) $ 58 $ 62 $ 66 Income tax benefit (1) (16) (17) (18) $ 42 $ 45 $ 48 Capitalized share-based compensation cost $ 9 $ 11 $ 11 Excess income tax (benefit) deficiency $ (9) $ (19) $ 4 SDG&E: Share-based compensation expense, before income taxes $ 10 $ 11 $ 10 Income tax benefit (3) (3) (3) $ 7 $ 8 $ 7 Capitalized share-based compensation cost $ 5 $ 7 $ 6 Excess income tax (benefit) deficiency $ (1) $ (3) $ 1 SoCalGas: Share-based compensation expense, before income taxes $ 14 $ 14 $ 15 Income tax benefit (4) (4) (4) $ 10 $ 10 $ 11 Capitalized share-based compensation cost $ 4 $ 4 $ 5 Excess income tax (benefit) deficiency $ (1) $ (3) $ 1 (1) Includes activity of awards issued from the IEnova 2013 LTIP, which settled in cash upon vesting based on the price of IEnova’s common stock. SEMPRA NONQUALIFIED STOCK OPTIONS We use a Black-Scholes option-pricing model to estimate the fair value of each nonqualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on a blend of the historical and implied volatility of Sempra’s common stock price. The average expected term for options is based on the vesting schedule, contractual term of the option, expected employee exercise and post-termination behavior. The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected term estimated at the date of the grant. In 2021, 2020 and 2019, Sempra’s board of directors granted 222,620, 154,860 and 261,075 nonqualified stock options, respectively, that are exercisable over a three KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Years ended December 31, 2021 2020 2019 Sempra: Stock price volatility 26.57 % 18.78 % 18.63 % Expected term 5.36 years 5.34 years 5.34 years Risk-free rate of return 0.41 % 1.68 % 2.49 % Annual dividend yield 3.38 % 2.60 % 3.35 % The following table shows a summary of nonqualified stock options at December 31, 2021 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value (in millions) Sempra: Outstanding at January 1, 2021 365,395 $ 120.93 Granted 222,620 $ 123.80 Exercised (50,671) $ 106.76 Outstanding at December 31, 2021 537,344 $ 123.45 8.06 $ 5 Vested or expected to vest at December 31, 2021 537,344 $ 123.45 8.06 $ 5 Exercisable at December 31, 2021 152,189 $ 118.10 7.27 $ 2 The aggregate intrinsic value at December 31, 2021 is the total of the difference between Sempra’s closing common stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for nonqualified stock options exercised in the last three years was: ▪ $1.4 million in 2021 ▪ $0.4 million in 2020 ▪ $4 million in 2019 We expect a negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.1 years. The weighted-average per-share fair values for nonqualified stock options granted in 2020 and 2019 was $149.12 and $106.76, respectively. We received cash of $5 million, a negligible amount and $3 million from stock option exercises in 2021, 2020 and 2019, respectively. SEMPRA RESTRICTED STOCK UNITS We use a Monte-Carlo simulation model to estimate the fair value of our RSUs that vest based on Sempra’s total return to shareholders. Our determination of fair value is affected by the historical volatility of the common stock price for Sempra and its peer group companies. The valuation also is affected by the risk-free rates of return and a number of other variables. Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2021 2020 2019 Sempra: Stock price volatility 33.39 % 16.35 % 17.74 % Risk-free rate of return 0.16 % 1.55 % 2.46 % The following table shows a summary of RSUs at December 31, 2021 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based restricted stock units Service-based restricted stock units Units Weighted- average grant-date fair value Units Weighted- average grant-date fair value Sempra: Nonvested at January 1, 2021 893,961 $ 121.61 343,577 $ 121.59 Granted 323,889 $ 133.03 143,980 $ 124.84 Vested (317,128) $ 105.03 (202,352) $ 116.28 Forfeited (29,945) $ 131.55 (7,905) $ 161.49 Nonvested at December 31, 2021 (1) 870,777 $ 131.64 277,300 $ 127.54 Expected to vest at December 31, 2021 854,697 $ 131.47 271,197 $ 127.47 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra exceeds target performance conditions. In 2021, 2020 and 2019, the total fair value of RSU shares vested during the year was $57 million, $70 million and $36 million, respectively. We expect $17 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.5 years. The weighted-average per-share fair values for performance-based RSUs granted were $155.62 and $113.54 in 2020 and 2019, respectively. The weighted-average per-share fair values for service-based RSUs granted were $138.91 and $112.50 in 2020 and 2019, respectively.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	DERIVATIVE FINANCIAL INSTRUMENTS We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that could cause our asset values to fall or our liabilities to increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Consolidated Balance Sheets. We may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for SDG&E and SoCalGas and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges and undesignated derivatives not subject to rate recovery). We classify cash flows from the principal settlements of cross-currency swaps that hedge exposure related to Mexican peso-denominated debt and hedge termination costs on interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Consolidated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪ SDG&E and SoCalGas use natural gas and electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. ▪ SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. ▪ Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. ▪ From time to time, our various businesses, including SDG&E and SoCalGas, may use other energy derivatives to hedge exposures such as GHG allowances. The following table summarizes net energy derivative volumes. NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) December 31, Commodity Unit of measure 2021 2020 2019 Sempra: Natural gas MMBtu 184 189 231 Electricity MWh 1 1 2 Congestion revenue rights MWh 45 43 48 SDG&E: Natural gas MMBtu 7 16 37 Electricity MWh 1 1 2 Congestion revenue rights MWh 45 43 48 SoCalGas: Natural gas MMBtu 201 185 201 INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments, at December 31: INTEREST RATE DERIVATIVES (Dollars in millions) 2021 2020 2019 Notional debt Maturities Notional debt Maturities Notional debt Maturities Sempra: Cash flow hedges $ 462 2022-2034 $ 1,486 2021-2034 $ 1,445 2020-2034 FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. We also utilized foreign currency derivatives in 2020 and 2019 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively. The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments, at December 31. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) 2021 2020 2019 Notional amount Maturities Notional amount Maturities Notional amount Maturities Sempra: Cross-currency swaps $ 306 2022-2023 $ 306 2021-2023 $ 306 2020-2023 Other foreign currency derivatives 106 2022-2023 1,764 2021-2022 1,796 2020-2021 FINANCIAL STATEMENT PRESENTATION The Consolidated Balance Sheets reflect the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Consolidated Balance Sheets, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2021 Other current Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 6 $ (6) $ (2) Foreign exchange instruments 1 1 (1) — Interest rate and foreign exchange instruments — — (1) (130) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 136 11 (122) (10) Associated offsetting commodity contracts (93) (8) 93 8 Commodity contracts subject to rate recovery 38 52 (58) — Associated offsetting commodity contracts (8) — 8 — Net amounts presented on the balance sheet 74 62 (87) (134) Additional cash collateral for commodity contracts not subject to rate recovery 58 — — — Additional cash collateral for commodity contracts subject to rate recovery 46 — — — Total (1) $ 178 $ 62 $ (87) $ (134) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 34 $ 52 $ (20) $ — Associated offsetting commodity contracts (5) — 5 — Net amounts presented on the balance sheet 29 52 (15) — Additional cash collateral for commodity contracts subject to rate recovery 28 — — — Total (1) $ 57 $ 52 $ (15) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ — $ (38) $ — Associated offsetting commodity contracts (3) — 3 — Net amounts presented on the balance sheet 1 — (35) — Additional cash collateral for commodity contracts subject to rate recovery 18 — — — Total $ 19 $ — $ (35) $ — (1) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2020 Other current Other long-term assets Other current Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 1 $ (16) $ (31) Foreign exchange instruments — — (9) (2) Interest rate and foreign exchange instruments — — (1) (127) Derivatives not designated as hedging instruments: Foreign exchange instruments 24 — — — Commodity contracts not subject to rate recovery 82 17 (95) (16) Associated offsetting commodity contracts (82) (13) 82 13 Commodity contracts subject to rate recovery 35 95 (35) (25) Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 57 100 (72) (188) Additional cash collateral for commodity contracts not subject to rate recovery 21 — — — Additional cash collateral for commodity contracts subject to rate recovery 30 — — — Total (1) $ 108 $ 100 $ (72) $ (188) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 32 $ 95 $ (28) $ (25) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 31 95 (27) (25) Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (1) $ 55 $ 95 $ (27) $ (25) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (7) $ — Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 2 — (6) — Additional cash collateral for commodity contracts subject to rate recovery 6 — — — Total $ 8 $ — $ (6) $ — (1) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2019 Other current Other long-term assets Other current Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 3 $ (11) $ (17) Foreign exchange instruments — — (6) (1) Interest rate and foreign exchange instruments — — — (122) Derivatives not designated as hedging instruments: Foreign exchange instruments 41 — (20) — Associated offsetting foreign exchange instruments (20) — 20 — Commodity contracts not subject to rate recovery 34 11 (41) (10) Associated offsetting commodity contracts (32) (2) 32 2 Commodity contracts subject to rate recovery 41 76 (47) (47) Associated offsetting commodity contracts (6) (3) 6 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 58 85 (53) (192) Additional cash collateral for commodity contracts not subject to rate recovery 43 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (1) $ 126 $ 85 $ (53) $ (192) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 30 $ 76 $ (41) $ (47) Associated offsetting commodity contracts (4) (3) 4 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 26 73 (23) (44) Additional cash collateral for commodity contracts subject to rate recovery 16 — — — Total (1) $ 42 $ 73 $ (23) $ (44) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 11 $ — $ (6) $ — Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 9 — (4) — Additional cash collateral for commodity contracts subject to rate recovery 9 — — — Total $ 18 $ — $ (4) $ — (1) Normal purchase contracts previously measured at fair value are excluded. The following table includes the effects of derivative instruments designated as cash flow hedges on the Consolidated Statements of Operations and in OCI and AOCI. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax (loss) gain reclassified Years ended December 31, Years ended December 31, 2021 2020 2019 Location 2021 2020 2019 Sempra: Interest rate instruments $ — $ — $ — Gain (Loss) on Sale of Assets $ — $ — $ (10) Interest rate instruments (1) 29 (34) (24) Interest Expense (1) (11) (10) (3) Interest rate instruments 71 (185) (164) Equity Earnings (2) (73) (46) (3) Foreign exchange instruments 11 (4) (8) Revenues: Energy- Related Businesses (1) 1 (2) Foreign exchange instruments 8 (3) (10) Equity Earnings (2) — — (2) Interest rate and foreign exchange instruments (4) (6) 19 Interest Expense (1) (1) — Other Income (Expense), Net (6) (11) 9 Total $ 115 $ (232) $ (187) $ (92) $ (67) $ (11) SDG&E: Interest rate instruments (1) $ — $ — $ (1) Interest Expense (1) $ — $ — $ (3) SoCalGas: Interest rate instruments $ — $ — $ — Interest Expense $ — $ — $ (1) (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. In August 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps. (2) Equity earnings at our foreign equity method investees are recognized after tax. For Sempra, we expect that net losses of $47 million, which are net of income tax benefit, that are currently recorded in AOCI (including $1 million in NCI) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature. For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at December 31, 2021 is approximately 13 years for Sempra. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 18 years. The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Years ended December 31, Location 2021 2020 2019 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ (203) $ 17 $ 12 Commodity contracts subject to rate recovery Cost of Natural Gas (25) (7) 3 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 31 88 (140) Foreign exchange instruments Other Income (Expense), Net (22) (56) 25 Total $ (219) $ 42 $ (100) SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 31 $ 88 $ (140) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (25) $ (7) $ 3 CONTINGENT FEATURES For Sempra, SDG&E and SoCalGas, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. For Sempra, the total fair value of this group of derivative instruments in a liability position at December 31, 2021, 2020 and 2019 was $88 million, $16 million and $21 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at December 31, 2021, 2020 and 2019 was $36 million, $6 million and $4 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at December 31, 2021 2020 or 2019. At December 31, 2021, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $88 million and $36 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS RECURRING FAIR VALUE MEASURES The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2021, 2020 and 2019. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair-valued assets and liabilities, and their placement within the fair value hierarchy. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 11 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following (other than a $5 million investment at December 31, 2019 measured at NAV): ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” ▪ Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). ▪ As we discuss in Note 6, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra Infrastructure.” RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 13 $ (10) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 8 — 56 Municipal bonds — 321 — 321 Other securities — 260 — 260 Total debt securities 48 589 — 637 Total nuclear decommissioning trusts (1) 419 585 — 1,004 Short-term investments held in Rabbi Trust 81 — — 81 Interest rate instruments — 6 — 6 Foreign exchange instruments — 2 — 2 Commodity contracts not subject to rate recovery — 46 — 46 Effect of netting and allocation of collateral (2) 58 — — 58 Commodity contracts subject to rate recovery 12 1 69 82 Effect of netting and allocation of collateral (2) 31 9 6 46 Support Agreement, net of related guarantee fees — — 7 7 Total $ 601 $ 649 $ 82 $ 1,332 Liabilities: Interest rate instruments $ — $ 8 $ — $ 8 Foreign exchange instruments — 1 — 1 Interest rate and foreign exchange instruments — 131 — 131 Commodity contracts not subject to rate recovery — 31 — 31 Commodity contracts subject to rate recovery — 35 15 50 Total $ — $ 206 $ 15 $ 221 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 9 $ (6) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 408 620 — 1,028 Short-term investments held in Rabbi Trust 61 — — 61 Interest rate instruments — 1 — 1 Foreign exchange instruments — 24 — 24 Commodity contracts not subject to rate recovery — 4 — 4 Effect of netting and allocation of collateral (2) 21 — — 21 Commodity contracts subject to rate recovery 6 1 121 128 Effect of netting and allocation of collateral (2) 19 5 6 30 Support Agreement, net of related guarantee fees — — 7 7 Total $ 515 $ 655 $ 134 $ 1,304 Liabilities: Interest rate instruments $ — $ 47 $ — $ 47 Foreign exchange instruments — 11 — 11 Interest rate and foreign exchange instruments — 128 — 128 Commodity contracts not subject to rate recovery — 16 — 16 Commodity contracts subject to rate recovery — 6 52 58 Support Agreement, net of related guarantee fees — — 4 4 Total $ — $ 208 $ 56 $ 264 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 14 $ 2 $ — $ 16 Equity securities 503 6 — 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 563 527 — 1,090 Short-term investments held in Rabbi Trust 66 — — 66 Interest rate instruments — 3 — 3 Foreign exchange instruments — 21 — 21 Commodity contracts not subject to rate recovery — 11 — 11 Effect of netting and allocation of collateral (2) 43 — — 43 Commodity contracts subject to rate recovery 5 8 95 108 Effect of netting and allocation of collateral (2) 11 8 6 25 Total $ 688 $ 578 $ 101 $ 1,367 Liabilities: Interest rate instruments $ — $ 28 $ — $ 28 Foreign exchange instruments — 7 — 7 Interest rate and foreign exchange instruments — 122 — 122 Commodity contracts not subject to rate recovery — 17 — 17 Commodity contracts subject to rate recovery 14 4 67 85 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 178 $ 67 $ 245 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 13 $ (10) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 8 — 56 Municipal bonds — 321 — 321 Other securities — 260 — 260 Total debt securities 48 589 — 637 Total nuclear decommissioning trusts (1) 419 585 — 1,004 Commodity contracts subject to rate recovery 12 — 69 81 Effect of netting and allocation of collateral (2) 22 — 6 28 Total $ 453 $ 585 $ 75 $ 1,113 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 15 $ 15 Total $ — $ — $ 15 $ 15 Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 9 $ (6) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 408 620 — 1,028 Commodity contracts subject to rate recovery 5 — 121 126 Effect of netting and allocation of collateral (2) 18 — 6 24 Total $ 431 $ 620 $ 127 $ 1,178 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 52 $ 52 Total $ — $ — $ 52 $ 52 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 14 $ 2 $ — $ 16 Equity securities 503 6 — 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 563 527 — 1,090 Commodity contracts subject to rate recovery 1 3 95 99 Effect of netting and allocation of collateral (2) 10 — 6 16 Total $ 574 $ 530 $ 101 $ 1,205 Liabilities: Commodity contracts subject to rate recovery $ 14 $ — $ 67 $ 81 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ — $ 67 $ 67 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Effect of netting and allocation of collateral (1) 9 9 — 18 Total $ 9 $ 10 $ — $ 19 Liabilities: Commodity contracts subject to rate recovery $ — $ 35 $ — $ 35 Total $ — $ 35 $ — $ 35 Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 1 $ — $ 2 Effect of netting and allocation of collateral (1) 1 5 — 6 Total $ 2 $ 6 $ — $ 8 Liabilities: Commodity contracts subject to rate recovery $ — $ 6 $ — $ 6 Total $ — $ 6 $ — $ 6 Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 4 $ 5 $ — $ 9 Effect of netting and allocation of collateral (1) 1 8 — 9 Total $ 5 $ 13 $ — $ 18 Liabilities: Commodity contracts subject to rate recovery $ — $ 4 $ — $ 4 Total $ — $ 4 $ — $ 4 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. Level 3 Information SDG&E The table below sets forth reconciliations of changes in the fair value of CRRs and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) Years ended December 31, 2021 2020 2019 Balance at January 1 $ 69 $ 28 $ 179 Realized and unrealized (losses) gains (50) 19 (184) Allocated transmission instruments 3 6 6 Settlements 32 16 27 Balance at December 31 $ 54 $ 69 $ 28 Change in unrealized (losses) gains relating to instruments still held at December 31 $ (16) $ 34 $ (139) (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following year. For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below: CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2022 $ (3.67) to $ 6.96 $ (0.70) 2021 (1.81) to 14.11 (0.12) 2020 (3.77) to 6.03 (1.58) The impact associated with discounting is negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 11. Long-term, fixed-price electricity positions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. The range and weighted-average price of these inputs at December 31 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2021 $ 24.10 to $ 105.00 $ 53.57 2020 19.60 to 78.10 39.71 2019 21.00 to 61.15 37.92 A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 11. Realized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Sempra Infrastructure The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra. LEVEL 3 RECONCILIATIONS (Dollars in millions) Years ended December 31, 2021 2020 Balance at January 1 $ 3 $ — Realized and unrealized gains (1) 11 6 Settlements (7) (3) Balance at December 31 (2) $ 7 $ 3 Change in unrealized gains relating to instruments still held at December 31 $ 11 $ 3 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations. (2) Balances at December 31, 2021 and 2020 include $7 and $7, respectively, in Other Current Assets, offset by a negligible amount and $4, respectively, in Deferred Credits and Other on Sempra’s Consolidated Balance Sheets. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, accounts receivable, short-term amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value amount Level 1 Level 2 Level 3 Total December 31, 2021 Sempra: Long-term note receivable (1) $ 300 $ — $ — $ 327 $ 327 Long-term amounts due from unconsolidated affiliates (2) 640 — 642 — 642 Long-term amounts due to unconsolidated affiliates 287 — 295 — 295 Total long-term debt (3) 20,099 — 22,126 — 22,126 SDG&E: Total long-term debt (4) $ 6,417 $ — $ 7,236 $ — $ 7,236 SoCalGas: Total long-term debt (5) $ 4,759 $ — $ 5,367 $ — $ 5,367 December 31, 2020 Sempra: Long-term amounts due from unconsolidated affiliates (2) $ 786 $ — $ 817 $ — $ 817 Long-term amounts due to unconsolidated affiliates 275 — 266 — 266 Total long-term debt (3) 22,259 — 25,478 — 25,478 SDG&E: Total long-term debt (4) $ 6,253 $ — $ 7,384 $ — $ 7,384 SoCalGas: Total long-term debt (5) $ 4,759 $ — $ 5,655 $ — $ 5,655 December 31, 2019 Sempra: Long-term amounts due from unconsolidated affiliates $ 742 $ — $ 759 $ — $ 759 Long-term amounts due to unconsolidated affiliates 195 — 184 — 184 Total long-term debt (3) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (4) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (5) $ 3,809 $ — $ 4,189 $ — $ 4,189 (1) Before allowances for credit losses of $8 and excluding transaction costs of $5 at December 31, 2021. (2) Before allowances for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively. Includes $2 and $3 of accrued interest receivable at December 31, 2021 and 2020, respectively, in Due From Unconsolidated Affiliate – Current. (3) Before reductions of unamortized discount and debt issuance costs of $260, $268 and $225 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,335, $1,330 and $1,289 at December 31, 2021 and 2020 and 2019, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $61, $52 and $48 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,274, $1,276 and $1,270 at December 31, 2021, 2020 and 2019, respectively. (5) Before reductions of unamortized discount and debt issuance costs of $36, $40 and $34 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $61, $54 and $19 at December 31, 2021, 2020 and 2019, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 15.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Preferred Stock	PREFERRED STOCKSempra and SDG&E are authorized to issue up to 50 million and 45 million shares of preferred stock, respectively. At December 31, 2021, 2020 and 2019, SDG&E had no preferred stock outstanding. The rights, preferences, privileges and restrictions for any new series of preferred stock would be established by each company’s board of directors at the time of issuance. We discuss SoCalGas preferred stock below. SEMPRA MANDATORY CONVERTIBLE PREFERRED STOCK On January 15, 2021, we converted 17,250,000 shares of series A preferred stock into 13,781,025 shares of our common stock based on a conversion rate of 0.7989 shares of our common stock for each issued and outstanding share of series A preferred stock. As a consequence, no shares of series A preferred stock were outstanding after January 15, 2021 and the 17,250,000 shares that were formerly series A preferred stock have returned to the status of authorized and unissued shares of preferred stock. As of July 15, 2021, we had converted, pursuant to either early conversions at the election of the holder or the mandatory conversion of all outstanding shares, all 5,750,000 shares of series B preferred stock into an aggregate of 4,256,720 shares of our common stock and a nominal amount of cash in lieu of fractional share interests, based on a conversion rate of 0.7403 shares of our common stock for each issued and outstanding share of series B preferred stock. As a consequence, no shares of series B preferred stock were outstanding after July 15, 2021 and the 5,750,000 shares that were formerly series B preferred stock have returned to the status of authorized and unissued shares of preferred stock. SEMPRA SERIES C PREFERRED STOCK In June 2020, we issued 900,000 shares of our 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C (series C preferred stock) in a registered public offering at a price to the public of $1,000 per share and received net proceeds of $889 million after deducting the underwriting discount and equity issuance costs of $11 million. We used the net proceeds for working capital and other general corporate purposes, including the repayment of indebtedness. Liquidation Preference Each share of series C preferred stock has a liquidation preference of $1,000 plus any accumulated and unpaid dividends (whether or not declared) on such share. Redemption at the Option of Sempra The shares of series C preferred stock are perpetual and have no maturity date. However, we may, at our option, redeem the series C preferred stock in whole or in part, from time to time, on any day during the period from and including the July 15 immediately preceding October 15, 2025 and October 15 of every fifth year after 2025 through and including such October 15 at a redemption price in cash equal to $1,000 per share. Additionally, in the event that a credit rating agency then publishing a rating for us makes certain amendments, clarifications or changes to the criteria it uses to assign equity credit to securities such as the series C preferred stock (Ratings Event), we may redeem the series C preferred stock, in whole but not in part, at any time within 120 days after the conclusion of any review or appeal process instituted by us following the occurrence of the Ratings Event or, if no such review or appeal process is available or sought, the occurrence of such Ratings Event, at a redemption price in cash equal to $1,020 per share (102% of the liquidation preference per share). Dividends Dividends on the series C preferred stock, when, as and if declared by our board of directors or an authorized committee thereof, are payable in cash, on a cumulative basis, semi-annually in arrears beginning on October 15, 2020. Dividends on the series C preferred stock will be cumulative whether or not: ▪ we have earnings; ▪ the payment of such dividends is then permitted under California law; ▪ such dividends are authorized or declared; and ▪ any agreements to which we are a party prohibit the current payment of dividends, including any agreement relating to our indebtedness. We accrue dividends on the series C preferred stock on a monthly basis. The dividend rate from and including June 19, 2020 to, but excluding, October 15, 2025 is 4.875% per annum of the $1,000 liquidation preference per share. The dividend rate will reset on October 15, 2025 and on October 15 of every fifth year after 2025 and, for each five-year period following such reset dates, will be a per annum rate equal to the Five-year U.S. Treasury Rate (as defined in the certificate of determination of preferences of the series C preferred stock) as of the second business day prior to such reset date, plus a spread of 4.550%, of the $1,000 liquidation preference per share. Voting Rights The holders of series C preferred stock do not have any voting rights, except with respect to any authorization, creation or increase in the authorized amount of any class or series of capital stock ranking senior to the series C preferred stock, certain amendments to the terms of the series C preferred stock, in certain other limited circumstances and as otherwise specifically required by California law. In addition, whenever dividends on any shares of series C preferred stock have not been declared and paid or have been declared but not paid for three or more dividend periods, whether or not consecutive, the authorized number of directors on our board of directors will automatically be increased by two and the holders of the series C preferred stock, voting together as a single class with holders of any and all other outstanding series of preferred stock of equal rank having similar voting rights, will be entitled to elect two directors who satisfy certain requirements to fill such two newly created directorships. This voting right will terminate when all accumulated and unpaid dividends on the series C preferred stock have been paid in full and, upon such termination and the termination of the same voting rights of all other holders of outstanding series of preferred stock that have such voting rights, the term of office of each director elected pursuant to such rights will terminate and the authorized number of directors will automatically decrease by two, subject to the revesting of such rights in the event of each subsequent nonpayment. Ranking The series C preferred stock ranks, with respect to dividend rights and distribution rights upon our liquidation, winding-up or dissolution: ▪ senior to our common stock and each other class or series of our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ on parity with each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks on parity with the series C preferred stock; ▪ junior to each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks senior to the series C preferred stock; ▪ junior to our existing and future indebtedness and other liabilities; and ▪ structurally subordinated to all existing and future indebtedness and other liabilities of our subsidiaries and capital stock of our subsidiaries held by third parties. SOCALGAS PREFERRED STOCK SoCalGas is authorized to issue up to an aggregate of 11 million shares of preferred stock, series preferred stock and preference stock. The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2021 2020 2019 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 19 SoCalGas - Total preferred stock 22 22 22 Less: 50,970 shares of the 6% Series outstanding owned by PE (2) (2) (2) Sempra - Total preferred stock of subsidiary $ 20 $ 20 $ 20 None of SoCalGas’ outstanding preferred stock is callable, and no shares are subject to mandatory redemption. All outstanding shares have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share plus any unpaid dividends. In addition to the outstanding preferred stock above, SoCalGas’ articles of incorporation authorize 5 million shares of series preferred stock and 5 million shares of preference stock, both without par value and with cumulative preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock and series preferred stock. Other rights and privileges of any new series of such stock would be established by the SoCalGas board of directors at the time of issuance.

SEMPRA - SHAREHOLDERS' EQUITY A

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE	SEMPRA – SHAREHOLDERS’ EQUITY AND EARNINGS PER COMMON SHARE SEMPRA COMMON STOCK REPURCHASES On September 11, 2007, our board of directors authorized the repurchase of shares of our common stock, provided that the amounts spent for such purpose do not exceed the greater of $2 billion or amounts spent to purchase no more than 40 million shares. On July 1, 2020, we entered into an ASR program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The total number of shares purchased was determined by dividing the $500 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of July 2, 2020 through August 4, 2020, minus a fixed discount. The ASR program was completed on August 4, 2020 with an aggregate of 4,089,375 shares of Sempra common stock repurchased at an average price of $122.27 per share. Following the completion of the ASR program, the aggregate dollar amount authorized by the September 11, 2007 share repurchase authorization was exhausted. On July 6, 2020, our board of directors authorized the repurchase of shares of our common stock at any time and from time to time in an aggregate amount not to exceed the lesser of $2 billion or amounts spent to purchase no more than 25 million shares. No shares were repurchased under this authorization in 2020. Beginning on November 17, 2021, we executed a series of open market repurchases for which we paid $300 million to repurchase shares of our common stock in the open market. The repurchases were completed on December 7, 2021 with an aggregate of 2,422,758 shares of Sempra common stock repurchased at a weighted-average purchase price of $123.83 per share, excluding commissions. On January 11, 2022, we entered into an ASR program under which we prepaid $200 million to repurchase shares of our common stock in a share forward transaction. A total of 1,472,756 shares were purchased under this program at an average price of $135.80 per share. The total number of shares purchased was determined by dividing the $200 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of January 12, 2022 through February 11, 2022, minus a fixed discount. The ASR program was completed on February 11, 2022. As of February 25, 2022, a maximum of $1.5 billion and no more than 21,104,486 shares may yet be purchased under the July 6, 2020 repurchase authorization. SETTLEMENT OF FORWARD SALE AGREEMENTS In 2019, we received $728 million (net of underwriting discounts of $13 million) from the settlement of 7,156,185 shares of our common stock at a forward sale price of $101.74 per share related to our January 2018 common stock offering. In 2019, we received $1,066 million (net of underwriting discounts of $18 million) from the settlement of 9,750,000 shares of our common stock at a forward sale price of $109.33 per share related to our July 2018 common stock offering. EARNINGS PER COMMON SHARE Basic EPS is calculated by dividing earnings attributable to common shares (from both continuing and discontinued operations) by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2021 2020 2019 Sempra: Numerator for continuing operations: Income from continuing operations, net of income tax $ 1,463 $ 2,255 $ 1,999 Earnings attributable to noncontrolling interests (145) (162) (129) Preferred dividends (63) (168) (142) Preferred dividends of subsidiary (1) (1) (1) Earnings from continuing operations attributable to common shares $ 1,254 $ 1,924 $ 1,727 Numerator for discontinued operations: Income from discontinued operations, net of income tax $ — $ 1,850 $ 363 Earnings attributable to noncontrolling interests — (10) (35) Earnings from discontinued operations attributable to common shares $ — $ 1,840 $ 328 Numerator for earnings: Earnings attributable to common shares $ 1,254 $ 3,764 $ 2,055 Denominator: Weighted-average common shares outstanding for basic EPS (1) 311,755 291,077 277,904 Dilutive effect of stock options and RSUs (2) 752 1,175 1,585 Dilutive effect of common shares sold forward — — 2,544 Dilutive effect of mandatory convertible preferred stock 529 — — Weighted-average common shares outstanding for diluted EPS 313,036 292,252 282,033 Basic EPS: Earnings from continuing operations $ 4.03 $ 6.61 $ 6.22 Earnings from discontinued operations $ — $ 6.32 $ 1.18 Earnings $ 4.03 $ 12.93 $ 7.40 Diluted EPS: Earnings from continuing operations $ 4.01 $ 6.58 $ 6.13 Earnings from discontinued operations $ — $ 6.30 $ 1.16 Earnings $ 4.01 $ 12.88 $ 7.29 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 453 in 2021, 537 in 2020 and 617 in 2019. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued. (2) Due to market fluctuations of both Sempra common stock and the comparative indices used to determine the vesting percentage of our total shareholder return performance-based RSUs, which we discuss in Note 10, dilutive RSUs may vary widely from period-to-period. The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for 2021, 2020 and 2019 excludes potentially dilutive shares related to stock options and RSUs of 211,155, 187,028 and 80,281, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future. The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we discuss above is reflected in our diluted EPS calculation using the treasury stock method. We have fully settled all forward sale agreements and those shares are included in weighted-average common shares outstanding for basic EPS. The potentially dilutive impact from our mandatory convertible preferred stock is calculated under the if-converted method until the mandatory conversion date. After the mandatory conversion date, the converted shares are included in weighted-average common shares outstanding for basic EPS. As we discuss in Note 13, we converted our series A preferred stock into common stock on January 15, 2021 and our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for the years ended December 31, 2021, 2020 and 2019 excludes 2,272,117, 17,889,365 and 17,471,375 potentially dilutive shares related to our mandatory convertible preferred stock, respectively, because to include them would be antidilutive for those periods. We are authorized to issue 750 million shares of no par value common stock. The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY Years ended December 31, 2021 2020 2019 Sempra: Common shares outstanding, January 1 288,470,244 291,712,925 273,769,513 Conversion of mandatory convertible preferred stock 18,037,745 — — Shares issued in IEnova exchange offer 12,306,777 — — Shares issued under forward sale agreements — — 16,906,185 RSUs vesting (1) 686,916 896,839 463,012 Stock options exercised 50,671 4,400 52,540 Savings plan issuance — 201,431 475,774 Common stock investment plan (2) — 42,955 199,253 Issuance of RSUs held in our Deferred Compensation Plan 102,238 103,552 59,470 Shares repurchased (3) (2,734,809) (4,491,858) (212,822) Common shares outstanding, December 31 316,919,782 288,470,244 291,712,925 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) In 2021 and 2020, includes shares repurchased under the repurchase programs that we discuss above. Generally, we purchase shares of our common stock or units from LTIP participants who elect to sell to us a sufficient number of vested RSUs to meet minimum statutory tax withholding requirements.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
SAN ONOFRE NUCLEAR GENERATING STATION	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2021 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (50) $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 125 22 (108) Pension and other postretirement benefit plan obligations (7) 50 103 Removal obligations (2,251) (2,121) (2,056) Environmental costs 62 56 45 Sunrise Powerlink fire mitigation 122 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 77 72 102 Gas transportation 49 35 22 Safety and reliability 67 67 77 Public purpose programs (107) (158) (124) 2019 GRC retroactive impacts — 56 111 Wildfire mitigation plan 178 93 12 Liability insurance premium 110 79 24 Other balancing accounts 207 61 70 Other regulatory assets (liabilities), net (2) 119 72 (153) Total SDG&E (1,299) (1,548) (1,746) SoCalGas: Deferred income taxes recoverable (refundable) in rates 44 (82) (203) Pension and other postretirement benefit plan obligations 51 417 400 Employee benefit costs 31 37 44 Removal obligations (627) (685) (728) Environmental costs 34 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (146) (56) (118) Safety and reliability 339 335 295 Public purpose programs (183) (253) (273) 2019 GRC retroactive impacts — 202 400 Liability insurance premium 16 7 4 Other balancing accounts 42 (65) (11) Other regulatory assets (liabilities), net (2) 142 75 (101) Total SoCalGas (257) (32) (251) Sempra Infrastructure: Deferred income taxes recoverable in rates 77 80 83 Other regulatory assets — — 6 Total Sempra $ (1,479) $ (1,500) $ (1,908) (1) At December 31, 2021, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $358, $139 and $108, respectively, and for SoCalGas was $410, $218 and $500, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. Regulatory Assets Not Earning a Return ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. The related amounts are recovered in rates once these contracts are settled, generally within two years. ▪ Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Infrastructure expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include excess deferred income taxes resulting from statutory income tax rate changes and certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 8. ▪ Regulatory assets/liabilities related to pension and other postretirement benefit plan obligations are offset by corresponding liabilities/assets. The assets are recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 48-year period. Regulatory Assets Earning a Return ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized amounts. Depreciation, taxes and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. The adopted revenue requirements in the 2019 GRC FD associated with the period from January 1, 2019 through December 31, 2019 were recovered in rates over a 24-month period that began in January 2020. Amortization expense on certain regulatory assets for the years ended December 31, 2021, 2020 and 2019 was $10 million, $9 million and $7 million, respectively, at Sempra, $5 million, $4 million and $3 million, respectively, at SDG&E, and $5 million, $5 million and $4 million, respectively, at SoCalGas. SEMPRA CALIFORNIA COVID-19 Pandemic Protections In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E and SoCalGas are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and will apply the amounts directly to eligible customer accounts to reduce past due balances. SDG&E and SoCalGas have been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. SDG&E and SoCalGas expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in future CPUC proceedings, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below. Disconnection OIR In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, SDG&E and SoCalGas have each established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. CPUC GRC The CPUC uses GRCs to set rates designed to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. In September 2019, the CPUC issued a final decision in the 2019 GRC approving SDG&E’s and SoCalGas’ test year revenues for 2019 and attrition year adjustments for 2020 and 2021, which was effective retroactively to January 1, 2019. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD approved a test year 2019 revenue requirement of $1,990 million for SDG&E’s combined operations ($1,590 million for its electric operations and $400 million for its natural gas operations) and $2,770 million for SoCalGas. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs. SDG&E and SoCalGas were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). In May 2021, the CPUC issued a final decision approving SDG&E’s and SoCalGas’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023. The 2019 GRC FD approved SDG&E’s and SoCalGas’ establishment of two-way liability insurance premium balancing accounts, including wildfire insurance premium costs based on a specific level of coverage. The 2019 GRC FD also permits SDG&E and SoCalGas to seek recovery of additional liability insurance coverage. The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time SDG&E and SoCalGas released these regulatory liability balances to revenues and regulatory interest. CPUC Cost of Capital A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 % The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index. Alternatively, under the CCM, SDG&E and SoCalGas are permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022. For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SDG&E and SoCalGas are required to file their next cost of capital applications in April 2022 for a January 1, 2023 effective date. SDG&E FERC Rate Matters SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar quarter until terminated by a notice at least six months before the end of the calendar year. In 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. Energy Efficiency Program Inquiry In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive. Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded that some concessions were appropriate, which include refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the year ended December 31, 2020, SDG&E reduced revenues by $51 million and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Consolidated Statements of Operations. The after-tax impact for the year ended December 31, 2020 was $44 million. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement. SOCALGAS OSCs – Energy Efficiency and Advocacy In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. On February 3, 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 can be appealed within 30 days or be reviewed by any of the CPUC commissioners. If there are no appeals or commissioner requests for review, POD 1 automatically becomes the final decision of the CPUC. SoCalGas does not intend to appeal POD 1. In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, the assigned Administrative Law Judge issued a modified POD 2 that substantially retains the original conclusions, including no fines or penalties. Also, in February 2022, a CPUC commissioner issued an alternative decision that imposes a financial penalty of $150,000. SoCalGas expects that both the modified POD 2 and the CPUC commissioner’s alternative decision will be heard at a CPUC meeting in March 2022. If the CPUC were to assess fines, penalties or other restrictions on SoCalGas that are different from what has been ordered in POD 1 and the modified POD 2, they could be material to SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra’s and SDG&E’s Consolidated Statements of Operations. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost. The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the foundation filed a notice of appeal. In September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the CCC’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. In December 2021, the foundation filed a request for dismissal. To date, decommissioning work has not been interrupted as a result of these writ petitions. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In December 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 12. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated At December 31, 2021: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 56 $ — $ — $ 56 Municipal bonds (2) 309 13 (1) 321 Other securities (3) 255 7 (2) 260 Total debt securities 620 20 (3) 637 Equity securities 104 262 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net 8 — — 8 Total $ 735 $ 282 $ (5) $ 1,012 At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 64 $ 1 $ — $ 65 Municipal bonds 308 18 — 326 Other securities 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Short-term investments, primarily cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2052. (2) Maturity dates are 2022-2056. (3) Maturity dates are 2022-2072. The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Proceeds from sales $ 961 $ 1,439 $ 914 Gross realized gains 67 156 24 Gross realized losses (5) (17) (5) Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. ASSET RETIREMENT OBLIGATION The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $568 million at December 31, 2021 and is based on a cost study prepared in 2020, which will be submitted to the CPUC in the first half of 2022. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $79 million in 2022, $66 million in 2023, $77 million in 2024, $46 million in 2025, $52 million in 2026, and $718 million thereafter. U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018, which is pending DOE approval. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.3 million of retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued. At December 31, 2021, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $2,086 million for Sempra, including $4 million for SDG&E and $2,006 million for SoCalGas. Amounts for Sempra and SoCalGas include $1,980 million for matters related to the Leak, which we discuss below. We discuss our policy regarding accrual of legal fees in Note 1. SoCalGas Aliso Canyon Natural Gas Storage Facility Gas Leak From October 23, 2015 through February 11, 2016, SoCalGas experienced a natural gas leak from one of the injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility in Los Angeles County. As described below, numerous lawsuits, investigations and regulatory proceedings have been initiated in response to the Leak, resulting in significant costs, which together with other Leak-related costs are discussed below in “Cost Estimates, Accounting Impact and Insurance.” Civil Litigation – Litigation Subject to Agreements to Resolve. As of February 18, 2022, approximately 390 lawsuits, including approximately 36,000 plaintiffs (the Individual Plaintiffs) were pending against SoCalGas and Sempra related to the Leak. All these cases are coordinated before a single court in the LA Superior Court for pretrial management. In November 2017, in the coordinated proceeding, a Third Amended Consolidated Master Case Complaint for Individual Actions was filed on behalf of the Individual Plaintiffs, through which their separate lawsuits are managed for pretrial purposes. The consolidated complaint asserts causes of action for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment, loss of consortium, wrongful death and violations of Proposition 65 against SoCalGas and Sempra (excluding the Proposition 65 claims, the Individual Plaintiff Litigation). The consolidated complaint seeks compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, injunctive relief, costs of future medical monitoring, civil penalties, and attorneys’ fees. In October 2018 and January 2019, complaints were filed on behalf of 51 firefighters stationed near the Aliso Canyon natural gas storage facility who allege they were injured by exposure to chemicals released during the Leak. The complaints against SoCalGas and Sempra assert causes of actions for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment and loss of consortium. The complaints seek compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, and attorneys’ fees. These complaints are included in the coordinated proceeding and the Individual Plaintiff Litigation. On September 26, 2021, SoCalGas and Sempra entered into an agreement with counsel representing over 80% of the plaintiffs in the Individual Plaintiff Litigation to resolve the claims of all Individual Plaintiffs for a payment of up to $1.8 billion. The agreement is subject to acceptance by no fewer than roughly 97% of all plaintiffs in the Individual Plaintiff Litigation by June 1, 2022, although SoCalGas and Sempra have the right to waive such condition. The agreement, which requires each plaintiff who accepts a settlement to release all such plaintiff’s claims against SoCalGas, Sempra and their respective affiliates related to the Individual Plaintiff Litigation and the Leak, provides that the settlement amount will be reduced based on the number of plaintiffs who do not accept. The LA Superior Court has approved the process to allocate payments among the plaintiffs. The plaintiffs who do not agree to participate in the settlement will be able to continue to pursue their claims. Pursuant to the agreement, the Individual Plaintiff Litigation has been stayed. In January 2017, two consolidated class action complaints were filed against SoCalGas and Sempra, one on behalf of a putative class of persons and businesses who own or lease real property within a five-mile radius of the well (the Property Class Action), and a second on behalf of a putative class of all persons and entities conducting business within five miles of the facility (the Business Class Action). The Property Class Action asserts claims for strict liability for ultra-hazardous activities, negligence, negligence per se, violation of the California Unfair Competition Law, trespass, permanent and continuing public and private nuisance, and inverse condemnation. The Business Class Action asserts a claim for violation of the California Unfair Competition Law. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. On September 26, 2021, SoCalGas and Sempra entered into an agreement to settle the Property Class Action for a total amount of $40 million. If, following a fairness hearing at which any objections to the settlement will be heard, the LA Superior Court gives final approval of the settlement, the agreement provides for a release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak by all property class members who do not opt out of the class. Members of the property class who opt out of the settlement will have the right to pursue their claims on an individual basis. On September 27, 2021, SoCalGas and Sempra entered into an agreement to settle the individual claims of the named plaintiffs in the Business Class Action for a total amount of $100,000 in exchange for a dismissal and release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak. The complaint was dismissed in January 2022. The Third Amended Consolidated Master Case Complaint for Individual Actions includes claims for violation of Proposition 65 seeking penalties for alleged violation of requirements to warn about certain chemical exposures as a result of the Leak. On November 4, 2021, SoCalGas entered into an agreement to settle these claims for a payment of approximately $2 million; in addition, SoCalGas agreed to implement certain measures to reduce emissions at the Aliso Canyon natural gas storage facility and to provide warnings to residents if benzene measured at the facility’s fence line exceeds certain levels. In January 2022, the LA Superior Court entered a consent judgment resolving the Proposition 65 claims. In October 2018 and October 2020, five property developers (the Developer Plaintiffs) filed complaints against SoCalGas and Sempra alleging causes of action for strict liability, negligence per se, negligence, negligent interference, continuing nuisance, permanent nuisance, inverse condemnation and violation of the California Unfair Competition Law and California Public Utilities Code section 2106, as well as claims for negligence against certain directors of SoCalGas. The complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In October 2021, the claims against the individual SoCalGas directors were dismissed. In January 2022, SoCalGas and Sempra entered into an agreement to settle the claims of one of the Developer Plaintiffs, and its complaint was dismissed. An adverse ruling in any of the lawsuits in the Individual Plaintiff Litigation filed by plaintiffs who do not agree to settle, any lawsuits filed by property class members who opt out of the Property Class Action settlement or by members of the putative Business Class Action could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. In addition, there can be no assurance that the conditions to resolve the Individual Plaintiff Litigation will be satisfied or that the LA Superior Court will approve the settlement for the Property Class Action. In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra and certain of its officers in July 2017 in the U.S. District Court for the Southern District of California. In March 2018, the court dismissed the action with prejudice, and in February 2021, the U.S. Court of Appeals for the Ninth Circuit affirmed the dismissal. The time for appeal has passed and, as a result, this represents the final judgment in this proceeding. Civil Litigation – Unresolved Litigation. The claims of four of the Developer Plaintiffs remain pending, and the LA Superior Court has scheduled a trial in October 2022. SoCalGas has engaged in settlement discussions with the Developer Plaintiffs. Four shareholder derivative actions were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra and/or SoCalGas. Three of the actions were joined in an Amended Consolidated Shareholder Derivative Complaint, which was dismissed with prejudice in January 2021. The plaintiffs have appealed the dismissal. The remaining action was also dismissed but plaintiffs were given leave to amend their complaint. Regulatory Proceedings. In January 2016, CalGEM and the CPUC directed an independent analysis of the technical root cause of the Leak to be conducted by Blade. In May 2019, Blade released its report, which concluded that the Leak was caused by a failure of the production casing of the well due to corrosion and that attempts to stop the Leak were not effectively conducted, but did not identify any instances of non-compliance by SoCalGas. Blade concluded that SoCalGas’ compliance activities conducted prior to the Leak did not find indications of a casing integrity issue. Blade opined, however, that there were measures, none of which were required by gas storage regulations at the time, that could have been taken to aid in the early identification of corrosion and that, in Blade’s opinion, would have prevented or mitigated the Leak. The report also identified well safety practices and regulations that have since been adopted by CalGEM and implemented by SoCalGas. In June 2019, the CPUC opened an OII to consider penalties against SoCalGas for the Leak, which it later bifurcated into two phases. The first phase will consider whether SoCalGas violated California Public Utilities Code Section 451 or other laws, CPUC orders or decisions, rules or requirements, whether SoCalGas engaged in unreasonable and/or imprudent practices with respect to its operation and maintenance of the Aliso Canyon natural gas storage facility or its related record-keeping practices, whether SoCalGas cooperated sufficiently with the SED of the CPUC and Blade during the pre-formal investigation, and whether any of the mitigation measures proposed by Blade should be implemented to the extent not already done. The SED, based largely on the Blade report, has alleged a total of 324 violations in the first phase, asserting that SoCalGas violated California Public Utilities Code Section 451 and failed to cooperate in the investigation and to keep proper records. Hearings on a subset of issues began in March 2021. The second phase will consider whether SoCalGas should be sanctioned for the Leak and what damages, fines or other penalties, if any, should be imposed for any violations, unreasonable or imprudent practices, or failure to cooperate sufficiently with the SED as determined by the CPUC in the first phase. In addition, the second phase will determine the amounts of various costs incurred by SoCalGas and other parties in connection with the Leak and the ratemaking treatment or other disposition of such costs, which could result in little or no recovery of such costs by SoCalGas. SoCalGas has engaged in settlement discussions with the SED in connection with this proceeding. In February 2017, the CPUC opened a proceeding pursuant to the SB 380 OII to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility while still maintaining energy and electric reliability for the region, but excluding issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. The first phase of the proceeding established a framework for the hydraulic, production cost and economic modeling assumptions for the potential reduction in usage or elimination of the Aliso Canyon natural gas storage facility. Phase 2 of the proceeding, which is evaluating the impacts of reducing or eliminating the Aliso Canyon natural gas storage facility using the established framework and models, began in the first quarter of 2019. In December 2019, the CPUC added a third phase of the proceeding and engaged a consultant who is analyzing alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2035 timeframe. In July 2021, the CPUC combined Phase 2 and Phase 3 and modified the scope of Phase 3 to also address potential implementation of alternatives to the Aliso Canyon natural gas storage facility if the CPUC determines that the Aliso Canyon natural gas storage facility should be permanently closed. The CPUC also added all California IOUs as parties to the proceeding and encouraged all load serving entities in the Los Angeles Basin to join the proceeding. In November 2020, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting the interim range between 0 Bcf and 34 Bcf. In November 2021, the CPUC issued a decision approving a new interim range of gas inventory levels of up to 41.16 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final inventory determination within the SB 380 OII proceeding. At December 31, 2021, the Aliso Canyon natural gas storage facility had a net book value of $883 million. If the Aliso Canyon natural gas storage facility were to be permanently closed or if future cash flows from its operation were otherwise insufficient to recover its carrying value, we may record an impairment of the facility, incur higher than expected operating costs and/or be required to make additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Any such outcome could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. Cost Estimate, Accounting Impact and Insurance. SoCalGas has incurred significant costs related to the Leak, primarily for temporary relocation of community residents; to control the well and stop the Leak; to mitigate the natural gas released; to purchase natural gas to replace what was lost through the Leak; to defend against and, in certain cases, settle, civil and criminal litigation arising from the Leak; to pay the costs of the government-ordered response to the Leak, including the costs for Blade to conduct the root cause analysis described above; to respond to various government and agency investigations regarding the Leak; and to comply with increased regulation imposed as a result of the Leak. At December 31, 2021, SoCalGas estimates these costs related to the Leak are $3,221 million (the cost estimate), which includes $1,279 million of costs recovered or probable of recovery from insurance. This cost estimate may increase significantly as more information becomes available. A portion of the cost estimate has been paid, and $1,983 million is accrued as Reserve for Aliso Canyon Costs at December 31, 2021 on SoCalGas’ and Sempra’s Consolidated Balance Sheets. In 2020, SoCalGas recorded $484 million in costs, inclusive of estimated legal costs, related to settlement discussions in connection with civil litigation and regulatory matters described above. Of this amount, $177 million was recorded in Insurance Receivable for Aliso Canyon Costs on the SoCalGas and Sempra Consolidated Balance Sheets and $307 million ($233 million after tax) was recorded in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Consolidated Statements of Operations. As a result of entering into the agreements described under “Civil Litigation – Litigation Subject to Agreements to Resolve” above, and other continuing settlement negotiations, SoCalGas recorded total charges of $1.59 billion ($1.15 billion after tax) in 2021 in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Consolidated Statements of Operations. Sempra elected to make an $800 million equity contribution to SoCalGas in September 2021 and may elect to make additional equity contributions in the future that are intended to maintain SoCalGas’ approved capital structure in connection with these accruals. Except for the amounts paid or estimated to settle certain legal and regulatory matters as described above, the cost estimate does not include (i) any amounts necessary to resolve claims of Individual Plaintiffs who do not agree to participate in the settlement of the Individual Actions or members of the Property Class Action who opt out of that settlement or (ii) the matters that we describe above in “Civil Litigation – Unresolved Litigation” and “Regulatory Proceedings” to the extent it is not possible to predict at this time the outcome of these actions or reasonably estimate the possible costs or a range of possible costs for damages, restitution, civil or administrative fines or penalties, defense, settlement or other costs or remedies that may be imposed or incurred. The cost estimate also does not include certain other costs incurred by Sempra associated with defending against shareholder derivative lawsuits and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued. These costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. We have received insurance payments for many of the categories of costs included in the cost estimate, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response to the Leak, certain legal costs and lost gas. At December 31, 2021, we recorded the expected recovery of the cost estimate related to the Leak of $360 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra’s Consolidated Balance Sheets. This amount is exclusive of insurance retentions and $919 million of insurance proceeds we received through December 31, 2021. We intend to pursue the full extent of our insurance coverage for the costs we have incurred. Other than insurance for certain future defense costs we may incur as well as directors’ and officers’ liability, we have exhausted all of our insurance in this matter. We continue to pursue other sources of insurance coverage for costs related to this matter, but we may not be successful in obtaining additional insurance recovery for any of these costs. If we are not able to secure additional insurance recovery, if any costs we have recorded as an insurance receivable are not collected, if there are delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts, which could be significant, could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. Sempra Infrastructure Energía Costa Azul We describe below certain land and customer disputes and permit challenges affecting our ECA Regas Facility and our proposed ECA LNG liquefaction projects. One or more unfavorable final decisions on these disputes or challenges could materially adversely affect our existing natural gas regasification operations and proposed natural gas liquefaction projects at the site of the ECA Regas Facility and have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects. Land Disputes. Sempra Infrastructure has been engaged in a long-running land dispute relating to property adjacent to its ECA Regas Facility that allegedly overlaps with land owned by the ECA Regas Facility (the facility, however, is not situated on the land that is the subject of this dispute), as follows: ▪ A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue title to him for the disputed property. In November 2013, the federal Agrarian Court ordered that SEDATU issue the requested title to the claimant and cause it to be registered. Both SEDATU and Sempra Infrastructure challenged the ruling due to lack of notification of the underlying process. In May 2019, a federal court in Mexico reversed the ruling and ordered a retrial, which is pending resolution. ▪ In a separate proceeding, the claimant filed suit to reinitiate an administrative procedure at SEDATU to obtain the property title that was previously dismissed. In April 2021, the Agrarian Court ordered that the administrative procedure be restarted. In addition, four cases involving two adjacent areas of real property on which part of the ECA Regas Facility is situated, each brought by a single plaintiff or her descendants, remain pending against the facility, as follows: ▪ The first disputed area is subject to a claim in the federal Agrarian Court that has been ongoing since 2006, in which the plaintiff seeks to annul the property title for a portion of the land on which the ECA Regas Facility is situated and to obtain possession of a different parcel that allegedly overlaps with the site of the ECA Regas Facility. The proceeding, which seeks an order that SEDATU annul the ECA Regas Facility’s competing property title, was initiated in 2006 and, in July 2021, a decision was issued in favor of the ECA Regas Facility. The plaintiff appealed, and in February 2022, the appellate court confirmed the ruling in favor the ECA Regas Facility and dismissed the appeal. ▪ The second disputed area is one parcel adjacent to the ECA Regas Facility that allegedly overlaps with land on which the ECA Regas Facility is situated, which is subject to a claim in the federal Agrarian Court and two claims in Mexican civil courts. The ECA Regas Facility first bought the property from the federal government in 2003; however, to resolve an ownership controversy, in 2008, the ECA Regas Facility reached a financial settlement with the plaintiff to eliminate an adverse claim to our title. Nevertheless, the plaintiff sued in 2013 for the nullity of both titles. The Agrarian Court ruled in favor of the plaintiff in May 2021, nullifying the first property title. Sempra Infrastructure appealed the ruling in July 2021, which is pending resolution. The ECA Regas Facility continues to hold the second property title to the land. The two civil court proceedings, which seek to invalidate the contract by which the ECA Regas Facility purchased for the second time the applicable parcel of land on which the ECA Regas Facility is situated on the grounds that the purchase price was allegedly unfair, are progressing at different stages. In the first civil case, initiated in 2013, the court ruled in favor of the ECA Regas Facility, and the final decision was affirmed on a federal appeal. The descendants of the same plaintiff filed the second civil case in 2019, which was dismissed by the court. However, the dismissal has been appealed, which is pending the appellate court’s ruling. Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities, including ECA LNG Phase 1 currently under construction, are proposed to be situated or on which portions of the ECA Regas Facility that would be necessary for the operation of the proposed ECA LNG liquefaction facilities are situated. Environmental and Social Impact Permits. Several administrative challenges are pending before Mexico’s Secretariat of Environment and Natural Resources (the Mexican environmental protection agency) and Federal Tax and Administrative Courts, seeking revocation of the environmental impact authorization issued to the ECA Regas Facility in 2003. These cases generally allege that the conditions and mitigation measures in the environmental impact authorization are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines. In 2018 and 2021, three related claimants filed separate challenges in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued by each of ASEA and SENER to ECA LNG authorizing natural gas liquefaction activities at the ECA Regas Facility, as follows: ▪ In the first case, the court issued a provisional injunction in September 2018. In December 2018, ASEA approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility in two phases. In May 2019, the court canceled the provisional injunction. The claimant appealed the court’s decision canceling the injunction, but was not successful. The claimant’s underlying challenge to the permits remains pending. ▪ In the second case, the initial request for a provisional injunction was denied. That decision was reversed on appeal in January 2020, resulting in the issuance of a new injunction against the permits that were issued by ASEA and SENER. This injunction has uncertain application absent clarification by the court. The claimants petitioned the court to rule that construction of natural gas liquefaction facilities violated the injunction, and in February 2022, the court ruled in favor of the ECA Regas Facility, meaning that the natural gas liquefaction activities have not been affected. The claimants may appeal this ruling. ▪ In the third case, a group of residents filed a complaint in June 2021 against various federal and state authorities alleging deficiencies in the public consultation process for the issuance of the permits. The request for an initial injunction was denied and the claimants have appealed, which is pending the appellate court’s ruling. Customer Dispute. In May 2020, the two third-party capacity customers at the ECA Regas Facility, Shell Mexico and Gazprom, asserted that a 2019 update of the general terms and conditions for service at the facility, as approved by the CRE, resulted in a breach of contract by Sempra Infrastructure and a force majeure event. Citing these circumstances, the customers subsequently stopped making payments of amounts due under their respective LNG storage and regasification agreements. Sempra Infrastructure has rejected the customers’ assertions and has drawn on the customers’ letters of credit provided as payment security. The parties engaged in discussions under the applicable contractual dispute resolution procedures without coming to a mutually acceptable resolution. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and although Gazprom has joined the proceeding, Gazprom has since replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. As a consequence, Sempra Infrastructure is not currently drawing on Gazprom’s letter of credit but expects to continue to draw on Shell Mexico’s letter of credit. Sempra Infrastructure intends to avail itself of its available claims, defenses, rights and remedies in the arbitration proceeding, including seeking dismissal of the customers’ claims. In addition to the arbitration proceeding, Shell Mexico also filed a constitutional challenge to the CRE’s approval of the update to the general terms and conditions and an additional constitutional claim against the issuance of the liquefaction permit. Shell Mexico’s request to stay the CRE’s approval of the general terms and conditions was denied and upheld on appeal. The claim regarding the liquefaction permit issuance was denied and is currently on appeal. A hearing on the merits of the arbitration case was held in October 2021. Sonora Pipeline Guaymas-El Oro Segment. Sempra Infrastructure’s Sonora natural gas pipeline consists of two segments, the Sasabe-Puerto Libertad-Guaymas segment and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. In 2015, the Yaqui tribe, with the exception of some members living in the Bácum community, granted its consent and a right-of-way easement agreement for the construction of the Guaymas-El Oro segment of the Sonora natural gas pipeline that crosses its territory. Representatives of the Bácum community filed a legal challenge in Mexican federal court demanding the right to withhold consent for the project, the stoppage of work in the Yaqui territory and damages. In 2016, the judge granted a suspension order that prohibited the construction of such segment through the Bácum community territory. Because the pipeline does not pass through the Bácum community, Sempra Infrastructure did not believe the 2016 suspension order prohibited construction in the remainder of the Yaqui territory. Construction of the Guaymas-El Oro segment was completed, and commercial operations began in May 2017. Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 2017 and, as a result, Sempra Infrastructure declared a force majeure event. In 2017, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory, which has prevented Sempra Infrastructure from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of Sempra Infrastructure and held that the Yaqui tribe was properly consulted and that consent from the Yaqui tribe was properly received. Representatives of the Bácum community appealed this decision, causing the suspension order preventing Sempra Infrastructure from repairing the damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory to remain in place until the appeals process is exhausted. In December 2021, the court of appeals referred the matter to Mexico’s Supreme Court. Sempra Infrastructure exercised its rights under the contract, which included seeking force majeure payments for the two-year period such force majeure payments were required to be made, which ended in August 2019. In July 2019, the CFE filed a request for arbitration generally to nullify certain contract terms that provide for fixed capacity payments in instances of force majeure and made a demand for substantial damages in connection with the force majeure event. In September 2019, the arbitration process ended when Sempra Infrastructure and the CFE reached an agreement to restart natural gas transportation service on the earlier of completion of repair of the damaged pipeline or January 15, 2020, and to modify the tariff structure and extend the term of the contract by 10 years. Subsequently, Sempra Infrastructure and the CFE agreed to extend the service start date multiple times, most recently to March 14,

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION We have four separately managed reportable segments, as follows: ▪ SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪ SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings, which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪ Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns an 80% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at December 31, 2021. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. The tables below include amounts from Sempra Renewables up until cessation of the segment. As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020. We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, the FERC. We describe the accounting policies of all of our segments in Note 1. The cost of common services shared by the business segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation. The following tables show selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 6. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2021 2020 2019 REVENUES SDG&E $ 5,504 $ 5,313 $ 4,925 SoCalGas 5,515 4,748 4,525 Sempra Infrastructure 1,997 1,400 1,454 Sempra Renewables — — 10 All other 5 2 3 Adjustments and eliminations (1) (3) (3) Intersegment revenues (1) (163) (90) (85) Total $ 12,857 $ 11,370 $ 10,829 DEPRECIATION AND AMORTIZATION SDG&E $ 889 $ 801 $ 760 SoCalGas 716 654 602 Sempra Infrastructure 239 198 193 All other 11 13 14 Total $ 1,855 $ 1,666 $ 1,569 INTEREST INCOME SDG&E $ 1 $ 2 $ 4 SoCalGas 1 2 2 Sempra Infrastructure 75 141 139 Sempra Renewables — — 11 All other 3 7 4 Intercompany eliminations (11) (56) (73) Total $ 69 $ 96 $ 87 INTEREST EXPENSE SDG&E $ 412 $ 413 $ 411 SoCalGas 157 158 141 Sempra Infrastructure 205 174 155 Sempra Renewables — — 3 All other 444 390 450 Intercompany eliminations (20) (54) (83) Total $ 1,198 $ 1,081 $ 1,077 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 201 $ 190 $ 171 SoCalGas (310) 96 120 Sempra Texas Utilities — 1 — Sempra Infrastructure 238 149 222 Sempra Renewables — — 4 All other (30) (187) (202) Total $ 99 $ 249 $ 315 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 819 $ 824 $ 767 SoCalGas (427) 504 641 Sempra Texas Utilities 616 579 528 Sempra Infrastructure 682 580 247 Sempra Renewables — — 59 Discontinued operations — 1,840 328 All other (436) (563) (515) Total $ 1,254 $ 3,764 $ 2,055 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2021 2020 2019 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 2,220 $ 1,942 $ 1,522 SoCalGas 1,984 1,843 1,439 Sempra Infrastructure 802 879 736 Sempra Renewables — — 2 All other 9 12 9 Total $ 5,015 $ 4,676 $ 3,708 ASSETS SDG&E $ 24,058 $ 22,311 $ 20,560 SoCalGas 20,324 18,460 17,077 Sempra Texas Utilities 13,047 12,542 11,619 Sempra Infrastructure 14,408 12,772 13,660 Discontinued operations — — 3,958 All other 1,399 1,215 763 Intersegment receivables (1,191) (677) (1,972) Total $ 72,045 $ 66,623 $ 65,665 GEOGRAPHIC INFORMATION Long-lived assets (2) : United States $ 50,657 $ 46,902 $ 43,719 Mexico $ 7,708 $ 6,929 $ 6,355 Asia 1 — — Total $ 58,366 $ 53,831 $ 50,074 Revenues (3) : United States $ 11,154 $ 10,205 $ 9,574 Mexico 1,703 1,165 1,255 Total $ 12,857 $ 11,370 $ 10,829 (1) Revenues for reportable segments include intersegment revenues of $10, $98, and $55 for 2021; $5, $88, and $(3) for 2020; and $5, $69, and $11 for 2019 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively. (2) Includes net PP&E and investments. (3) Amounts are based on where the revenue originated, after intercompany eliminations.

SCHEDULE I - CONDENSED FINANCIA

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information of Parent	SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2021 2020 2019 Interest income $ 11 $ 4 $ 3 Interest expense (576) (495) (521) Operating expenses (92) (86) (124) Other income (expense), net 20 (38) 59 Income tax benefit 190 176 163 Loss before equity in earnings of subsidiaries (447) (439) (420) Equity in earnings of subsidiaries, net of income taxes 1,764 4,371 2,617 Net income 1,317 3,932 2,197 Preferred dividends (63) (168) (142) Earnings $ 1,254 $ 3,764 $ 2,055 Basic EPS: Earnings $ 4.03 $ 12.93 $ 7.40 Weighted-average common shares outstanding 311,755 291,077 277,904 Diluted EPS: Earnings $ 4.01 $ 12.88 $ 7.29 Weighted-average common shares outstanding 313,036 292,252 282,033 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2021, 2020 and 2019 Pretax Income tax benefit (expense) Net-of-tax 2021: Net income $ 1,127 $ 190 $ 1,317 Other comprehensive income (loss): Foreign currency translation adjustments (6) — (6) Financial instruments 191 (47) 144 Pension and other postretirement benefits 28 (6) 22 Total other comprehensive income 213 (53) 160 Comprehensive income $ 1,340 $ 137 $ 1,477 2020: Net income $ 3,756 $ 176 $ 3,932 Other comprehensive income (loss): Foreign currency translation adjustments 547 — 547 Financial instruments (146) 33 (113) Pension and other postretirement benefits 11 1 12 Total other comprehensive income 412 34 446 Comprehensive income $ 4,168 $ 210 $ 4,378 2019: Net income $ 2,034 $ 163 $ 2,197 Other comprehensive income (loss): Foreign currency translation adjustments (43) — (43) Financial instruments (161) 53 (108) Pension and other postretirement benefits 25 (7) 18 Total other comprehensive loss (179) 46 (133) Comprehensive income $ 1,855 $ 209 $ 2,064 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, 2021 2020 2019 Assets: Cash and cash equivalents $ 186 $ 366 $ 6 Restricted cash 2 — — Due from affiliates 446 58 98 Income taxes receivable, net — 42 — Other current assets 31 26 34 Total current assets 665 492 138 Investments in subsidiaries 33,308 33,898 32,604 Due from affiliates 21 1 3 Deferred income taxes 626 2,187 1,766 Other long-term assets 1,090 717 682 Total assets $ 35,710 $ 37,295 $ 35,193 Liabilities and shareholders’ equity: Short-term debt $ 1,240 $ — $ — Current portion of long-term debt — 850 1,399 Due to affiliates 185 224 369 Income taxes payable, net 4 — 274 Other current liabilities 531 536 561 Total current liabilities 1,960 1,610 2,603 Long-term debt 5,969 7,317 8,856 Due to affiliates 1,151 4,375 3,138 Other long-term liabilities 649 620 667 Commitments and contingencies (Note 4) Shareholders’ equity 25,981 23,373 19,929 Total liabilities and shareholders’ equity $ 35,710 $ 37,295 $ 35,193 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2021 2020 2019 Net cash (used in) provided by operating activities $ (255) $ (978) $ 294 Expenditures for property, plant and equipment (8) (9) (8) Capital contributions to investees (1,005) (364) (1,528) Disbursement for note receivable (305) — — Distribution from investments 1,552 3,616 — (Increase) decrease in loans to affiliates, net (20) 2 — Other — — 4 Net cash provided by (used in) investing activities 214 3,245 (1,532) Common stock dividends paid (1,331) (1,174) (993) Preferred dividends paid (99) (157) (142) Issuances of preferred stock, net — 891 — Issuances of common stock, net 5 11 1,830 Repurchases of common stock (339) (566) (26) Issuances of long-term debt 990 1,599 758 Payments on long-term debt (3,200) (3,700) (1,500) Increase in short-term debt 1,240 — — Increase in loans from affiliates, net 1,092 1,194 1,328 Purchases of noncontrolling interest (217) — — Proceeds from sale of noncontrolling interest 1,846 — — Equity transaction costs with third parties — (4) — Debt issuance costs — (1) (25) Make-whole premiums related to early redemptions of debt (121) — — Other financing (2) — — Net cash (used in) provided by financing activities (136) (1,907) 1,230 Effect of exchange rate changes on cash and cash equivalents (1) — — (Decrease) increase in cash and cash equivalents (178) 360 (8) Cash and cash equivalents, January 1 366 6 14 Cash, cash equivalents and restricted cash, December 31 $ 188 $ 366 $ 6 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Issuance of common stock in exchange for NCI and related AOCI $ 1,373 $ — $ — Common dividends issued in stock — 22 55 Common dividends declared but not paid 349 301 283 Conversion of mandatory convertible preferred stock 2,258 — — Preferred dividends declared but not paid 11 47 36 Equitization of amounts due from affiliates 4,351 — — See Notes to Condensed Financial Information of Parent. The condensed financial information of Sempra Energy has been prepared in accordance with SEC Regulation S-X Rule 5-04 and Rule 12-04. We apply the same accounting policies as in the financial statements of Sempra, except that Sempra Energy accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information. Sempra Energy received cash dividends from its consolidated subsidiaries totaling $375 million, $300 million and $150 million in 2021, 2020 and 2019, respectively. We describe below and in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had or may have a significant effect on Sempra Energy’s results of operations, financial condition, cash flows or disclosures. ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts. SHORT-TERM DEBT Committed Line of Credit At December 31, 2021, Sempra Energy had an aggregate capacity of $4.4 billion under two primary committed lines of credit and available unused credit of $3.1 billion, which provide liquidity and support its commercial paper program. The amount of commercial paper outstanding, before reduction of any unamortized discount, and any letters of credit outstanding is reflected as a reduction to the available unused credit. The principal terms of Sempra Energy’s committed lines of credit include the following: ▪ Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in the facility. ▪ One facility provides for the issuance of $200 million of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra Energy has the right to increase its letter of credit commitment to $500 million. No letters of credit were outstanding at December 31, 2021. ▪ Borrowings bear interest at a benchmark rate plus a margin that varies with Sempra Energy’s credit rating. ▪ Sempra Energy must maintain a ratio of indebtedness to total capitalization (as defined in its credit facility) of no more than 65% at the end of each quarter. At December 31, 2021, Sempra Energy was in compliance with this ratio under credit facility. LONG-TERM DEBT The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2021 2020 2019 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 6,058 8,258 10,358 Current portion of long-term debt — (850) (1,399) Unamortized discount on long-term debt (37) (32) (35) Unamortized debt issuance costs (52) (59) (68) Total long-term debt $ 5,969 $ 7,317 $ 8,856 (1) Callable long-term debt not subject to make-whole provisions. In December 2021, Sempra Energy redeemed, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon the early redemptions, we recognized $126 million ($92 million after tax) in charges associated with the make-whole premiums and a write-off of unamortized discount and debt issuance costs. In November 2021, we issued $1.0 billion of 4.125% fixed-to-fixed reset rate junior subordinated notes maturing on April 1, 2052. Interest on the notes accrues from and including November 19, 2021 and is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on April 1, 2022. The notes will bear interest (i) from and including November 19, 2021 to, but excluding, April 1, 2027 at the rate of 4.125% per annum and (ii) from and including April 1, 2027, during each subsequent five-year period beginning on April 1 of every fifth year, at a rate per annum equal to the Five-year U.S. Treasury Rate (as defined in the notes) as of the day falling two business days before the first day of such five-year period plus a spread of 2.868%, to be reset on April 1 of every fifth year beginning in 2027. We received proceeds of $988 million (net of underwriting discounts and debt issuance costs of $12 million). We used the proceeds from the offering to repay a portion of the aggregate principal amount of the $2.35 billion of senior unsecured notes that we discuss above. At December 31, 2021, long-term debt maturities totaling $6.1 billion commence after 2026. Additional information on Sempra Energy’s long-term debt is provided in Note 7 of the Notes to Consolidated Financial Statements. Sempra Energy has an operating lease commitment related to its corporate headquarters building of approximately $279 million. Sempra Energy expects payments for its operating lease to be $11 million in 2022, $12 million in each of 2023 through 2026 and $220 million thereafter. For other contingencies and guarantees related to Sempra Energy, refer to Notes 6 and 16 of the Notes to Consolidated Financial Statements.

SIGNIFICANT ACCOUNTING POLICI_2

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, a new segment that includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Through an internal reorganization, we consolidated the assets of our LNG business (previously included in our Sempra LNG segment) and our ownership of IEnova (previously included in our Sempra Mexico segment) under Sempra Global (previously included in Parent and other), which was renamed SI Partners. This reorganization simplifies Sempra’s ownership and management of its non-utility, energy infrastructure assets in North America by consolidating them under a single platform. As a result, the Sempra LNG and Sempra Mexico segments no longer exist. Our historical segment disclosures have been restated to conform with the current presentation, so that all discussions of our reportable segments reflect the revised segment information of our four separate reportable segments, which we discuss in Note 17. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E was the primary beneficiary until August 23, 2019, at which time SDG&E deconsolidated the VIE, as we discuss below in “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova, which is a wholly owned subsidiary of Sempra. SoCalGas SoCalGas’ common stock is wholly owned by PE, which is a wholly owned subsidiary of Sempra.
Basis of Presentation	BASIS OF PRESENTATION This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. References in this report to “we,” “our,” “us” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We sometimes refer to SDG&E and SoCalGas collectively as Sempra California. SI Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity. Throughout these Notes, we refer to the following as Consolidated Financial Statements and Notes to Consolidated Financial Statements when discussed together or collectively: ▪ the Consolidated Financial Statements and related Notes of Sempra; ▪ the Consolidated Financial Statements and related Notes of SDG&E; and ▪ the Financial Statements and related Notes of SoCalGas.
Use of Estimates in the Preparation of the Financial Statements	Use of Estimates in the Preparation of the Financial Statements We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates.
Discontinued Operations	Discontinued Operations We completed the sales of our equity interests in our Peruvian businesses in April 2020 and our Chilean businesses in June 2020. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria upon our decision to sell them in January 2019. These
Subsequent Events	Subsequent Events We evaluated events and transactions that occurred after December 31, 2021 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation.
Regulated Operations	REGULATED OPERATIONS SDG&E’s and SoCalGas’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, the FERC, requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Sempra Infrastructure’s natural gas distribution utility, Ecogas, also applies U.S. GAAP for rate-regulated utilities to its operations, including the same evaluation of probability of recovery of regulatory assets described above. Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and certain cities and are subject to regulatory rate-setting processes and earnings oversight. Oncor and Sharyland Utilities prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. Our Sempra Infrastructure segment includes the operating companies of our subsidiary, IEnova, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below in “Property, Plant and Equipment.”
Fair Value Measurements	FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily NDT and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, short-term investments, and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and fixed-price electricity positions at SDG&E and the Support Agreement at Sempra Infrastructure. The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following (other than a $5 million investment at December 31, 2019 measured at NAV): ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” ▪ Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). ▪ As we discuss in Note 6, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra Infrastructure.”
Cash and Cash Equivalents and Restricted Cash	CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase. Restricted cash includes: ▪ for Sempra Infrastructure, funds denominated in Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects
Credit Losses	CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in a sales-type lease and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 6. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered.
Concentration of Credit Risk	CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by the respective credit departments at each of our segments and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a regular basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: ▪ prospective counterparties’ financial condition (including credit ratings) ▪ collateral requirements ▪ the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty ▪ downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance in our allowances for credit losses. When our development projects become operational, we rely significantly on the ability of suppliers to perform under long-term agreements and on our ability to enforce contract terms in the event of nonperformance. Also, the factors that we consider in evaluating a development project include negotiating customer and supplier agreements and, therefore, we rely on these agreements for future performance. We also may condition our decision to go forward on development projects on first obtaining these customer and supplier agreements.
Inventories	INVENTORIES SDG&E and SoCalGas value natural gas inventory using the last-in first-out method. As inventories are sold, differences between the last-in first-out valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent if the natural gas inventory withdrawn from storage during the year is not replaced by year end. SDG&E and SoCalGas generally value materials and supplies at the lower of average cost or net realizable value. Sempra Infrastructure values natural gas inventory and materials and supplies at the lower of average cost or net realizable value, and LNG inventory using the first-in first-out method.
Income Taxes	INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. Investment tax credits from prior years are amortized to income by SDG&E and SoCalGas over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, SDG&E, SoCalGas and Sempra Infrastructure recognize: ▪ regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪ regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR.
Greenhouse Gas Allowances and Obligations and Emissions and Renewable Energy Certificates	GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS SDG&E, SoCalGas and Sempra Infrastructure are required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation. At SDG&E and SoCalGas, many GHG allowances are allocated to us on behalf of our customers at no cost. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Infrastructure records the cost of GHG obligations in cost of sales. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. RENEWABLE ENERGY CERTIFICATES RECs are energy rights established by governmental agencies for the environmental and social promotion of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable energy PPAs, internal generation or separate purchases in the market to comply with the RPS Program established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with the RPS Program. The cost of RECs at SDG&E, which is recoverable in rates, is recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations.
Property, Plant and Equipment (PP&E)	PROPERTY, PLANT AND EQUIPMENTPP&E is recorded at cost and primarily represents the buildings, equipment and other facilities used by SDG&E and SoCalGas to provide natural gas and electric utility services, and by the Sempra Infrastructure businesses in their operations, including construction work in progress. PP&E also includes lease improvements and other equipment at Parent and other. Our plant costs include labor, materials and contract services and expenditures for replacement parts incurred during a major maintenance outage of a plant. In addition, the cost of utility plant at our rate-regulated businesses and PP&E under regulated projects that meet the regulatory accounting requirements of U.S. GAAP includes AFUDC. The cost of PP&E for our non-regulated projects includes capitalized interest. Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. Depreciation expense is computed using the straight-line method over the asset’s estimated composite useful life, the CPUC-prescribed period for SDG&E and SoCalGas, or the remaining term of the site leases, whichever is shortest.
Capitalized Finance Costs	SDG&E and SoCalGas finance construction projects with debt and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of PP&E. SDG&E and SoCalGas earn a return on the capitalized AFUDC after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives of the assets. Pipeline projects under construction by Sempra Infrastructure that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC.
Goodwill and Other Intangible Assets	GOODWILL AND OTHER INTANGIBLE ASSETS Goodwill Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies measured at the time of acquisition. Goodwill is not amortized, but we test it for impairment annually on October 1 or whenever events or changes in circumstances necessitate an evaluation. If the carrying value of the reporting unit, including goodwill, exceeds its fair value, we record a goodwill impairment loss as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. Other Intangible Assets at December 31, 2021 primarily include: ▪ renewable energy transmission and consumption permits previously granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar; ▪ a favorable O&M agreement acquired in connection with the acquisition of DEN; and ▪ the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ in March 2021.
Long-lived Assets	LONG-LIVED ASSETS We test long-lived assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets. Long-lived assets include intangible assets subject to amortization, but do not include investments in unconsolidated entities. A long-lived asset may be impaired when the estimated future undiscounted cash flows are less than the carrying amount of the asset. If that comparison indicates that the asset’s carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the asset. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
Variable Interest Entities	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess: ▪ the purpose and design of the VIE; ▪ the nature of the VIE’s risks and the risks we absorb; ▪ the power to direct activities that most significantly impact the economic performance of the VIE; and ▪ the obligation to absorb losses or the right to receive benefits that could be significant to the VIE.
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record AROs for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost using the present value of the obligation at the time the asset is placed into service, and recognize that cost over the life of the related asset by depreciating the asset retirement cost and accreting the obligation until the liability is settled. Our rate-regulated entities record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with U.S. GAAP and costs recovered through the rate-making process.
Contingencies	CONTINGENCIES We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and if: ▪ information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and ▪ the amount of the loss or a range of possible losses can be reasonably estimated. We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
Legal Fees	LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred and amounts are estimable. LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.
Comprehensive Income	COMPREHENSIVE INCOME Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including: ▪ foreign currency translation adjustments ▪ certain hedging activities ▪ changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans
Noncontrolling Interests	NONCONTROLLING INTERESTS Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI.
Operation and Maintenance Expenses	OPERATION AND MAINTENANCE EXPENSES Operation and Maintenance includes O&M and general and administrative costs, consisting primarily of personnel costs, purchased materials and services, insurance, rent and litigation expense (except for litigation expense included in Aliso Canyon Litigation and Regulatory Matters).
Foreign Currency Translation	FOREIGN CURRENCY TRANSLATION AND TRANSACTIONS Our natural gas distribution utility in Mexico, Ecogas, and the majority of our former operations in South America (until our sale of these operations in 2020) use their local currency as their functional currency. The assets and liabilities of their foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings, but are reflected in OCI and in AOCI. Cash flows of these consolidated foreign subsidiaries are translated into U.S. dollars using average exchange rates for the period. We report the effect of exchange rate changes on cash balances held in foreign currencies in Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash on Sempra’s Consolidated Statements of Cash Flows.
New Accounting Standards	ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts.
Revenue from Contract with Customer	Our revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity service is provided to our customers and we invoice our customers for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Our performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of our performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in our customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ ability to collect from the customer, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: ▪ The transmission, distribution and storage of natural gas at: ◦ SDG&E ◦ SoCalGas ◦ Sempra Infrastructure’s Ecogas ▪ The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill our customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, which follow the provisions of U.S. GAAP governing rate-regulated operations as we discuss in Note 1, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue for customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. SDG&E and SoCalGas recognize revenues from the sale of allocated California GHG emissions allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and SDG&E and SoCalGas have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Revenues at Sempra Infrastructure typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. As we discuss in Note 5, in February 2019, Sempra Infrastructure completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas). We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency translation and the actual quantity of commodity transported. Sempra Infrastructure and, previously, Sempra Renewables develop, invest in and operate solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, and also for Sempra Infrastructure, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated and delivered. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. As we discuss in Note 5, in April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities, as the power is delivered at the interconnection point. Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure. SoCalGas did not have any remaining performance obligations at December 31, 2021. REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled revenues. As discussed earlier, the regulatory framework requires SDG&E and SoCalGas to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive mechanisms. The CPUC applies performance-based measures and incentive mechanisms to all California IOUs, under which SDG&E and SoCalGas have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize SDG&E and SoCalGas to collect revenue requirements for operating costs and capital related costs (such as depreciation, taxes and return on rate base) from customers, including: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded within a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met at the time the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund for programs authorized, including limitations on the total cost of the program, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in disallowances of recovery from ratepayers. We discuss balancing accounts and their effects further in Note 4. Other Revenues Sempra Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and liquid fuels terminals. Certain PPAs at Sempra Renewables were accounted for as operating leases prior to sale of its wind assets in April 2019. We discuss the recognition of lease income in Note 16 of the Notes to Consolidated Financial Statements. Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes. Sempra Infrastructure also recognizes other revenues associated with derivatives related to the sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of these derivatives.
Investments in Noncontrolling Interests	We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Consolidated Statements of Operations. Our equity method investments include various domestic and foreign entities. Our domestic equity method investees are typically partnerships that are pass-through entities for income tax purposes and therefore they do not record income tax. Sempra’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense on the Consolidated Statements of Operations. Our foreign equity method investees are generally corporations whose operations are taxable on a standalone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax. See Note 8 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.
Employee Benefit Plans	Plan Assets Investment Allocation Strategy for Sempra’s Pension Master Trust Sempra’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. We maintain additional trusts, as we discuss below, for certain of SDGE’s and SoCalGas’ PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks. Currently, the pension plans’ target asset allocations are: ▪ 31% domestic equity ▪ 21% international equity ▪ 21% long credit ▪ 10% diversified real assets ▪ 10% return-seeking credit ▪ 5% ultra-long duration government securities ▪ 2% other diversifying assets The asset allocation of the plans is reviewed by our Plan Funding Committee and our Pension and Benefits Investment Committee (the Committees) on a regular basis. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪ long-term cost ▪ variability and level of contributions ▪ funded status ▪ a range of expected outcomes over varying confidence levels This allocation results in a 74% target allocation to return-seeking assets and a 26% target allocation to risk-mitigating assets. We maintain asset allocations at strategic levels with reasonable bands of variance. In accordance with the Sempra pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on assets in our pension and PBOP plans is based on the weighted-average of the plans’ investment allocations to specific asset classes as of the measurement date. We arrive at a 6.75% expected return on assets by considering both the historical and forecasted long-term rates of return on those asset classes. We expect a return of between 4% and 12% on return-seeking assets and between 1% and 4% for risk-mitigating assets. Certain trusts that hold assets for the SDG&E other postretirement benefit plan are subject to taxation, which impacts the expected after-tax return on assets in the plan. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. Investment Strategy for SDG&E’s and SoCalGas’ Other Postretirement Benefit Plans SDG&E’s and SoCalGas’ PBOP plans are funded by cash contributions from SDG&E and SoCalGas and their current retirees. The assets of these plans are placed into the pension master trust and other Voluntary Employee Beneficiary Association trusts. Certain assets of SDG&E’s and SoCalGas’ PBOP plans are held in the pension master trust, which invests a portion of the assets in completion portfolios that aim to reduce interest rate risk, thereby resulting in an overall target allocation of 38% to return-seeking assets and 62% to risk-mitigating assets for these well-funded plans. Certain of SoCalGas’ PBOP plans are held in a Voluntary Employee Benefit Association trust that also utilizes a completion portfolio, resulting in a target allocation of 30% to return-seeking assets and 70% to risk-mitigating assets. SDG&E’s and SoCalGas’ assets held in other Voluntary Employee Beneficiary Association trusts are invested in accordance with a de-risking glidepath that reduces the assets’ exposure to risk as the trusts become better funded. These specific allocations are periodically reviewed to help ensure that plan assets are best positioned to meet plan obligations.
Share-based Compensation	Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases.We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three four
Derivative Financial Instruments	We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that could cause our asset values to fall or our liabilities to increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Consolidated Balance Sheets. We may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for SDG&E and SoCalGas and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges and undesignated derivatives not subject to rate recovery). We classify cash flows from the principal settlements of cross-currency swaps that hedge exposure related to Mexican peso-denominated debt and hedge termination costs on interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Consolidated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪ SDG&E and SoCalGas use natural gas and electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. ▪ SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. ▪ Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. ▪ From time to time, our various businesses, including SDG&E and SoCalGas, may use other energy derivatives to hedge exposures such as GHG allowances. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. We also utilized foreign currency derivatives in 2020 and 2019 to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively.
Earnings Per Share	Basic EPS is calculated by dividing earnings attributable to common shares (from both continuing and discontinued operations) by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect.
Leases	As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and liquid fuels terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record a corresponding ROU asset, initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. We test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets. For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. SDG&E and SoCalGas recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. SDG&E and SoCalGas recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. Our leases do not contain any material residual value guarantees, restrictions or covenants.
Lessor, Leases	Generally, we recognize operating lease income on a straight-line basis over the lease term, and sales-type lease income based on the effective interest method over the lease term. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next.
Environmental Costs	We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: At SDG&E and SoCalGas, costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates. The environmental issues currently facing us, except for those related to the Leak as we discuss above or resolved during the last three years, include (1) investigation and remediation of SDG&E’s and SoCalGas’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by SDG&E and SoCalGas at which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS.
Segment Reporting	We have four separately managed reportable segments, as follows: ▪ SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪ SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings, which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪ Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns an 80% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at December 31, 2021. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. The tables below include amounts from Sempra Renewables up until cessation of the segment. As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020. We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, the FERC. We describe the accounting policies of all of our segments in Note 1.

SIGNIFICANT ACCOUNTING POLICI_3

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) At December 31, 2021 2020 2019 Cash and cash equivalents $ 559 $ 960 $ 108 Restricted cash, current 19 22 31 Restricted cash, noncurrent 3 3 3 Cash, cash equivalents and restricted cash in discontinued operations — — 75 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 581 $ 985 $ 217
Schedule of Accounts Receivable, Allowance for Credit Loss	We provide below allowances and changes in allowances for credit losses for trade receivables and other receivables. SDG&E and SoCalGas record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts. RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Allowances for credit losses at January 1 $ 138 $ 29 $ 21 Incremental allowance upon adoption of ASU 2016-13 — 1 — Provisions for expected credit losses 45 124 22 Write-offs (47) (16) (14) Allowances for credit losses at December 31 $ 136 $ 138 $ 29 SDG&E: Allowances for credit losses at January 1 $ 69 $ 14 $ 11 Provisions for expected credit losses 23 65 10 Write-offs (26) (10) (7) Allowances for credit losses at December 31 $ 66 $ 69 $ 14 SoCalGas: Allowances for credit losses at January 1 $ 68 $ 15 $ 10 Provisions for expected credit losses 22 59 12 Write-offs (21) (6) (7) Allowances for credit losses at December 31 $ 69 $ 68 $ 15 Allowances for credit losses are included in the Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) December 31, 2021 2020 2019 Sempra: Accounts receivable – trade, net $ 94 $ 111 $ 7 Accounts receivable – other, net 39 27 22 Other long-term assets 3 — — Total allowances for credit losses $ 136 $ 138 $ 29 SDG&E: Accounts receivable – trade, net $ 42 $ 55 $ 4 Accounts receivable – other, net 22 14 10 Other long-term assets 2 — — Total allowances for credit losses $ 66 $ 69 $ 14 SoCalGas: Accounts receivable – trade, net $ 51 $ 55 $ 3 Accounts receivable – other, net 17 13 12 Other long-term assets 1 — — Total allowances for credit losses $ 69 $ 68 $ 15
Schedule of Inventory	The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2021 2020 2019 2021 2020 2019 2021 2020 2019 Natural gas $ 164 $ 118 $ 110 $ — $ — $ 1 $ 114 $ 94 $ 90 LNG 27 7 9 — — — — — — Materials and supplies 198 183 158 123 104 93 58 59 46 Total $ 389 $ 308 $ 277 $ 123 $ 104 $ 94 $ 172 $ 153 $ 136
Wildfire Fund	The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2021 2020 2019 Wildfire Fund asset: Current Prepaid Expenses $ 29 $ 29 $ 29 Noncurrent Wildfire Fund 331 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 $ 13 Noncurrent Deferred Credits and Other 64 75 86 Years ended December 31, 2021 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 29 $ 12 Impairment of Wildfire Fund asset Impairment Losses (1) 3 — — Accretion of Wildfire Fund obligation Operation and Maintenance 2 2 1 (1) Included in O&M for SDG&E. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 %
Schedule of Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) December 31, Depreciation rates for years ended 2021 2020 2019 2021 2020 2019 SDG&E: Natural gas operations $ 3,200 $ 2,805 $ 2,534 2.55 % 2.51 % 2.47 % Electric distribution 9,471 8,592 7,985 3.93 3.90 3.94 Electric transmission (1) 7,577 7,156 6,577 3.02 3.10 2.79 Electric generation 2,446 2,440 2,415 4.74 4.56 4.50 Other electric 2,100 1,743 1,492 7.23 6.92 6.61 Construction work in progress (1) 1,662 1,700 1,501 NA NA NA Total SDG&E 26,456 24,436 22,504 SoCalGas: Natural gas operations 21,894 19,961 18,370 3.65 3.63 3.60 Other non-utility 50 45 34 2.23 3.80 5.08 Construction work in progress 1,160 1,174 958 NA NA NA Total SoCalGas 23,104 21,180 19,362 Sempra Infrastructure and parent (2) : Estimated useful lives Weighted-average useful life Land and land rights 291 283 278 16 to 50 years (3) 36 Machinery and equipment: Pipelines and storage 3,698 3,482 3,596 5 to 50 years 42 Generating plants 1,659 1,288 1,154 11 to 30 years 27 LNG terminals 1,138 1,138 1,134 43 years 43 Liquid fuels terminals 420 — — 37 years 37 Other 370 359 180 3 to 50 years 13 Construction work in progress 1,494 1,514 895 NA NA Other 310 248 226 4 to 50 years 21 9,380 8,312 7,463 Total Sempra $ 58,940 $ 53,928 $ 49,329 (1) At December 31, 2021, includes $542 in electric transmission assets and $5 in construction work in progress related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. SDG&E’s share of operating expenses is included in Sempra’s and SDG&E’s Consolidated Statements of Operations. (2) Includes $211, $191 and $178 at December 31, 2021, 2020, and 2019, respectively, of utility plant, primarily pipelines and other distribution assets at Ecogas. (3) Estimated useful lives are for land rights. DEPRECIATION EXPENSE (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra $ 1,833 $ 1,646 $ 1,551 SDG&E 884 797 757 SoCalGas 711 649 598 ACCUMULATED DEPRECIATION AND AMORTIZATION (Dollars in millions) December 31, 2021 2020 2019 SDG&E: Accumulated depreciation: Natural gas operations $ 919 $ 870 $ 832 Electric transmission, distribution and generation (1) 5,489 5,145 4,705 Total SDG&E 6,408 6,015 5,537 SoCalGas: Accumulated depreciation: Natural gas operations 6,845 6,422 6,023 Other non-utility 16 15 15 Total SoCalGas 6,861 6,437 6,038 Sempra Infrastructure and parent: Accumulated depreciation – other (2) 1,777 1,473 1,302 Total Sempra $ 15,046 $ 13,925 $ 12,877 (1) Includes $292 at December 31, 2021 related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities.
Schedule Of Capitalized Financing Costs	The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest. CAPITALIZED FINANCING COSTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra $ 217 $ 202 $ 183 SDG&E 106 104 75 SoCalGas 64 55 47
Schedule Of Other Intangible Assets	Other Intangible Assets included on Sempra’s Consolidated Balance Sheets are as follows: OTHER INTANGIBLE ASSETS (Dollars in millions) Amortization period December 31, 2021 2020 2019 Renewable energy transmission and consumption permits 15 to 19 $ 169 $ 169 $ 169 O&M agreement 23 66 66 66 ESJ PPA 14 190 — — Other 10 to indefinite 15 15 15 440 250 250 Less accumulated amortization: Renewable energy transmission and consumption permits (40) (32) (24) O&M agreement (12) (9) (6) ESJ PPA (10) — — Other (8) (7) (7) (70) (48) (37) $ 370 $ 202 $ 213
Schedule Of Asset Retirement Obligations	The changes in AROs are as follows: CHANGES IN ASSET RETIREMENT OBLIGATIONS (Dollars in millions) Sempra SDG&E SoCalGas 2021 2020 2019 2021 2020 2019 2021 2020 2019 Balance as of January 1 (1) $ 3,289 $ 3,083 $ 2,972 $ 876 $ 866 $ 874 $ 2,368 $ 2,177 $ 2,063 Accretion expense 133 127 123 38 39 39 92 86 81 Liabilities incurred and acquired 20 2 2 2 — — — — — Deconsolidation — — (2) — — (2) — — — Payments (63) (63) (46) (60) (60) (44) (3) (2) (2) Revisions (2) 159 140 34 34 31 (1) 125 107 35 Balance at December 31 (1) $ 3,538 $ 3,289 $ 3,083 $ 890 $ 876 $ 866 $ 2,582 $ 2,368 $ 2,177 (1) Current portion of the ARO for Sempra is included in Other Current Liabilities on the Consolidated Balance Sheets. (2) SDG&E’s increase in ARO in 2021 includes $22 million due to a revised estimate related to the decommissioning of SONGS, which is offset in noncurrent Regulatory Assets.
Schedule Of Changes In Accumulated Other Comprehensive Income By Component	The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, excluding amounts attributable to NCI. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (Dollars in millions) Foreign Financial Pension Total Sempra (2) : Balance as of December 31, 2018 $ (564) $ (82) $ (118) $ (764) Adoption of ASU 2018-02 — (25) (17) (42) OCI before reclassifications (3) (43) (116) (18) (177) Amounts reclassified from AOCI (3) — 8 36 44 Net OCI (43) (108) 18 (133) Balance as of December 31, 2019 (607) (215) (117) (939) OCI before reclassifications (3)(4) (102) (163) (26) (291) Amounts reclassified from AOCI (3) 645 47 38 730 Net OCI (4) 543 (116) 12 439 Balance as of December 31, 2020 (64) (331) (105) (500) OCI before reclassifications (4) (34) 62 8 36 Amounts reclassified from AOCI (5) 19 113 14 146 Net OCI (4)(5) (15) 175 22 182 Balance as of December 31, 2021 $ (79) $ (156) $ (83) $ (318) SDG&E: Balance as of December 31, 2018 $ (10) $ (10) Adoption of ASU 2018-02 (2) (2) OCI before reclassifications (5) (5) Amounts reclassified from AOCI 1 1 Net OCI (4) (4) Balance as of December 31, 2019 (16) (16) OCI before reclassifications (3) (4) (4) Amounts reclassified from AOCI (3) 10 10 Net OCI 6 6 Balance as of December 31, 2020 (10) (10) OCI before reclassifications (1) (1) Amounts reclassified from AOCI 1 1 Net OCI — — Balance as of December 31, 2021 $ (10) $ (10) SoCalGas: Balance as of December 31, 2018 $ (12) $ (8) $ (20) Adoption of ASU 2018-02 (2) (2) (4) OCI before reclassifications — (4) (4) Amounts reclassified from AOCI (3) 1 4 5 Net OCI 1 — 1 Balance as of December 31, 2019 (13) (10) (23) OCI before reclassifications (3) — (10) (10) Amounts reclassified from AOCI (3) — 2 2 Net OCI — (8) (8) Balance as of December 31, 2020 (13) (18) (31) OCI before reclassifications — (2) (2) Amounts reclassified from AOCI — 2 2 Net OCI — — — Balance as of December 31, 2021 $ (13) $ (18) $ (31) (1) All amounts are net of income tax, if subject to tax, and exclude NCI. (2) Includes discontinued operations in 2020 and 2019. (3) Pension and Other Postretirement Benefits and Total AOCI include $6 in transfers of liabilities from SDG&E to SoCalGas and $3 in transfers of liabilities from SDG&E to Sempra in 2020 and $4 in transfers of liabilities from SoCalGas to Sempra in 2019 related to the nonqualified pension plans. (4) Total AOCI includes $28 of foreign currency translation adjustments and $16 of financial instruments associated with the IEnova exchange and cash tender offers in 2021. Total AOCI includes $4 of foreign currency translation adjustments and $3 of financial instruments associated with IEnova’s repurchases of NCI in 2020. We discuss these transactions below in “Other Noncontrolling Interests – Sempra Infrastructure.” These transactions do not impact the Consolidated Statements of Comprehensive Income (Loss). (5) Total AOCI includes $19 of foreign currency translation adjustments and $47 of financial instruments associated with the sale of NCI to KKR in 2021. We discuss this transaction below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction does not impact the Consolidated Statements of Comprehensive Income (Loss).
Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated Amounts reclassified from accumulated Affected line item on Years ended December 31, 2021 2020 2019 Sempra: Foreign currency translation adjustments $ — $ 645 $ — Income from Discontinued Operations, Net of Income Tax Financial instruments: Interest rate instruments $ — $ — $ 10 Gain (Loss) on Sale of Assets Interest rate instruments (1) 11 10 3 Interest Expense Interest rate instruments 73 46 3 Equity Earnings (2) Foreign exchange instruments 1 (1) 2 Revenues: Energy-Related Businesses Foreign exchange instruments — — 2 Equity Earnings (2) Interest rate and foreign exchange instruments 1 1 — Interest Expense 6 11 (9) Other Income (Expense) , Net Total before income tax 92 67 11 (24) (19) (2) Income Tax Expense Net of income tax 68 48 9 (2) (1) (1) Earnings Attributable to Noncontrolling Interests $ 66 $ 47 $ 8 Pension and other postretirement benefits (3) : Amortization of actuarial loss $ 8 $ 8 $ 12 Other Income (Expense), Net Amortization of actuarial loss — 6 1 Income from Discontinued Operations, Net of Income Tax Amortization of prior service cost 4 4 3 Other Income (Expense), Net Settlement charges 7 22 28 Other Income (Expense), Net Total before income tax 19 40 44 — (2) — Income from Discontinued Operations, Net of Income Tax (5) (9) (12) Income Tax Expense Net of income tax $ 14 $ 29 $ 32 Total reclassifications for the period, net of tax $ 80 $ 721 $ 40 SDG&E: Financial instruments: Interest rate instruments (1) $ — $ — $ 3 Interest Expense — — (3) Earnings Attributable to Noncontrolling Interest $ — $ — $ — Pension and other postretirement benefits (3) : Amortization of actuarial loss $ — $ 1 $ — Other Income, Net Amortization of prior service cost 1 1 1 Other Income, Net Total before income tax 1 2 1 — (1) — Income Tax Expense Net of income tax $ 1 $ 1 $ 1 Total reclassifications for the period, net of tax $ 1 $ 1 $ 1 SoCalGas: Financial instruments: Interest rate instruments $ — $ — $ 1 Interest Expense Pension and other postretirement benefits (3) : Amortization of actuarial loss $ 1 $ 1 $ 1 Other Expense, Net Amortization of prior service cost 1 1 — Other Expense, Net Total before income tax 2 2 1 — — (1) Income Tax Benefit (Expense) Net of income tax $ 2 $ 2 $ — Total reclassifications for the period, net of tax $ 2 $ 2 $ 1 (1) Amounts in 2019 include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. (2) Equity earnings at our foreign equity method investees are recognized after tax. (3) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” in Note 9).
Schedule Of Noncontrolling Interests	The following table provides information about NCI held by others in subsidiaries or entities consolidated by us and recorded in Other Noncontrolling Interests in Total Equity on Sempra’s Consolidated Balance Sheets. OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by Equity held by December 31, December 31, 2021 2020 2019 2021 2020 2019 Sempra Infrastructure: SI Partners 20.0 % — % — % $ 1,384 $ — $ — SI Partners subsidiaries (1) 0.1 - 16.6 17.5 - 29.8 10.0 - 46.3 34 1,540 1,622 Parent and other: PXiSE — 20.0 20.0 — 1 1 Discontinued Operations: Chilquinta Energía subsidiaries (1) — — 19.7 - 43.4 — — 23 Luz del Sur — — 16.4 — — 205 Tecsur — — 9.8 — — 5 Total Sempra $ 1,418 $ 1,541 $ 1,856 (1) SI Partners and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
Schedule of Related Party Transactions	TRANSACTIONS WITH AFFILIATES We summarize amounts due from and to unconsolidated affiliates at Sempra, SDG&E and SoCalGas in the following table. AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) December 31, 2021 2020 2019 Sempra: Total due from various unconsolidated affiliates – current $ 23 $ 20 $ 32 Sempra Infrastructure: ESJ JV – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020 (1) $ — $ 85 $ — IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively (2) 637 695 742 Total due from unconsolidated affiliates – noncurrent $ 637 $ 780 $ 742 Sempra Infrastructure – TAG Pipelines Norte, S. de R.L. de C.V. – Note due December 20, 2021 (3)(4) $ — $ (41) $ — Various affiliates — (4) (5) Total due to unconsolidated affiliates – current $ — $ (45) $ (5) Sempra Infrastructure (4) : TAG Pipelines Norte, S. de R.L. de C.V.: Note due December 20, 2021 (3) $ — $ — $ (39) 5.5% Note due January 9, 2024 (5) (69) (68) — 5.5% Note due January 14, 2025 (5) (21) — — 5.5% Note due July 16, 2025 (5) (20) — — TAG JV – 5.74% Note due December 17, 2029 (5) (177) (166) (156) Total due to unconsolidated affiliates – noncurrent $ (287) $ (234) $ (195) SDG&E: Sempra $ (40) $ (38) $ (37) SoCalGas (48) (21) (10) Various affiliates (9) (5) (6) Total due to unconsolidated affiliates – current $ (97) $ (64) $ (53) Income taxes due from Sempra (6) $ 19 $ — $ 130 SoCalGas: SDG&E $ 48 $ 21 $ 10 Various affiliates 1 1 1 Total due from unconsolidated affiliates – current $ 49 $ 22 $ 11 Sempra $ (36) $ (31) $ (45) Various affiliates — — (2) Total due to unconsolidated affiliates – current $ (36) $ (31) $ (47) Income taxes due from (to) Sempra (6) $ 6 $ (37) $ 152 (1) U.S. dollar-denominated loan at a variable interest rate based on 1-month LIBOR plus 196 bps (2.11% at December 31, 2020). At December 31, 2020, $1 of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. In March 2021, Sempra Infrastructure acquired the remaining 50% equity interest in ESJ that it did not already own, and ESJ became a wholly owned, consolidated subsidiary, resulting in the elimination of this note receivable. (2) Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $691 U.S. dollar-equivalent at December 31, 2021, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (8.06% at December 31, 2021), to finance construction of a natural gas marine pipeline. At both December 31, 2021 and 2020, $2 of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. At December 31, 2021, we classified this revolving line of credit as noncurrent because we expect to extend the maturity date on a long-term basis prior to its stated maturity date. (3) U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.16% at December 31, 2020). (4) Amounts include principal balances plus accumulated interest outstanding. (5) U.S. dollar-denominated loan at a fixed interest rate. (6) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra, and their respective income tax expense is computed as an amount equal to that which would result from each company having always filed a separate return. The following table summarizes income statement information from unconsolidated affiliates. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Revenues $ 31 $ 37 $ 52 Cost of sales 11 45 50 Interest income 50 56 74 Interest expense 15 14 2 SDG&E: Revenues $ 11 $ 6 $ 6 Cost of sales 103 79 74 SoCalGas: Revenues $ 98 $ 88 $ 69 Cost of sales (1) 1 — 8
Schedule Of Other Income (Expense)	Other Income (Expense), Net on the Consolidated Statements of Operations consists of the following: OTHER INCOME (EXPENSE), NET (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Allowance for equity funds used during construction $ 133 $ 128 $ 94 Investment gains, net (1) 50 41 61 (Losses) gains on interest rate and foreign exchange instruments, net (28) (67) 34 Foreign currency transaction (losses) gains, net (2) (18) (25) 21 Non-service component of net periodic benefit cost (67) (102) (132) Interest on regulatory balancing accounts, net 6 14 14 Sundry, net (18) (37) (15) Total $ 58 $ (48) $ 77 SDG&E: Allowance for equity funds used during construction $ 81 $ 79 $ 56 Non-service component of net periodic benefit cost (13) (20) (20) Interest on regulatory balancing accounts, net 6 9 13 Sundry, net (10) (16) (10) Total $ 64 $ 52 $ 39 SoCalGas: Allowance for equity funds used during construction $ 48 $ 41 $ 34 Non-service component of net periodic benefit cost (40) (54) (72) Interest on regulatory balancing accounts, net — 5 1 Sundry, net (22) (20) (18) Total $ (14) $ (28) $ (55) (1) Represents net investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are offset by corresponding changes in compensation expense related to the plans, recorded in O&M on the Consolidated Statements of Operations. (2) Includes losses of $23 in 2021, losses of $42 in 2020 and gains of $30 in 2019 from translation to U.S. dollars of a Mexican peso-denominated loan to IMG JV, which are offset by corresponding amounts included in Equity Earnings on the Consolidated Statements of Operations.

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregation of Revenue	The following table disaggregates our revenues from contracts with customers by major service line and market and provides a reconciliation to total revenues by segment. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Sempra Infrastructure Sempra Renewables Consolidating adjustments and Parent and other Sempra Year ended December 31, 2021 By major service line: Utilities $ 5,144 $ 5,424 $ 81 $ — $ (109) $ 10,540 Energy-related businesses — — 1,165 — (29) 1,136 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 By market: Gas $ 790 $ 5,424 $ 856 $ — $ (101) $ 6,969 Electric 4,354 — 390 — (37) 4,707 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 Revenues from contracts with customers $ 5,144 $ 5,424 $ 1,246 $ — $ (138) $ 11,676 Utilities regulatory revenues 360 91 — — — 451 Other revenues — — 751 — (21) 730 Total revenues $ 5,504 $ 5,515 $ 1,997 $ — $ (159) $ 12,857 Year ended December 31, 2020 By major service line: Utilities $ 4,920 $ 4,571 $ 58 $ — $ (94) $ 9,455 Energy-related businesses — — 854 — 1 855 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 By market: Gas $ 692 $ 4,571 $ 623 $ — $ (90) $ 5,796 Electric 4,228 — 289 — (3) 4,514 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 Revenues from contracts with customers $ 4,920 $ 4,571 $ 912 $ — $ (93) $ 10,310 Utilities regulatory revenues 393 177 — — — 570 Other revenues — — 488 — 2 490 Total revenues $ 5,313 $ 4,748 $ 1,400 $ — $ (91) $ 11,370 Year ended December 31, 2019 By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ (75) $ 9,184 Energy-related businesses — — 951 5 1 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 By market: Gas $ 587 $ 4,367 $ 711 $ — $ (69) $ 5,596 Electric 4,232 — 313 5 (5) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 1,024 $ 5 $ (74) $ 10,141 Utilities regulatory revenues 106 158 — — — 264 Other revenues — — 430 5 (11) 424 Total revenues $ 4,925 $ 4,525 $ 1,454 $ 10 $ (85) $ 10,829
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at December 31, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure. SoCalGas did not have any remaining performance obligations at December 31, 2021. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2022 $ 368 $ 4 2023 367 4 2024 365 4 2025 362 4 2026 361 4 Thereafter 4,289 63 Total revenues to be recognized $ 6,112 $ 83
Schedule of Contract Liabilities	Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in 2021, 2020 or 2019. CONTRACT LIABILITIES (Dollars in millions) 2021 2020 2019 Sempra: Contract liabilities at January 1 $ (207) $ (163) $ (70) Revenue from performance obligations satisfied during reporting period 52 4 2 Payments received in advance (123) (48) (95) Contract liabilities at December 31 (1) $ (278) $ (207) $ (163) SDG&E: Contract liabilities at January 1 $ (87) $ (91) $ — Revenue from performance obligations satisfied during reporting period 4 4 1 Payments received in advance — — (92) Contract liabilities at December 31 (2) $ (83) $ (87) $ (91) (1) Balances at December 31, 2021, 2020 and 2019 include $116, $52 and $4, respectively, in Other Current Liabilities and $162, $155 and $159, respectively, in Deferred Credits and Other. (2)
Schedule of Contract Accounts Receivable	The table below shows receivable balances associated with revenues from contracts with customers on the Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2021 2020 2019 Sempra: Accounts receivable – trade, net $ 1,886 $ 1,447 $ 1,163 Accounts receivable – other, net 19 12 16 Due from unconsolidated affiliates – current (1) 2 3 5 Other long-term assets 70 — — Total $ 1,977 $ 1,462 $ 1,184 SDG&E: Accounts receivable – trade, net $ 715 $ 573 $ 398 Accounts receivable – other, net 9 8 5 Due from unconsolidated affiliates – current (1) 2 2 2 Other long-term assets 25 — — Total $ 751 $ 583 $ 405 SoCalGas: Accounts receivable – trade, net $ 1,084 $ 786 $ 710 Accounts receivable – other, net 10 4 11 Other long-term assets 45 — — Total $ 1,139 $ 790 $ 721 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Consolidated Balance Sheets, when right of offset exists.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Schedule of Regulatory Assets	We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2021 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (50) $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 125 22 (108) Pension and other postretirement benefit plan obligations (7) 50 103 Removal obligations (2,251) (2,121) (2,056) Environmental costs 62 56 45 Sunrise Powerlink fire mitigation 122 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 77 72 102 Gas transportation 49 35 22 Safety and reliability 67 67 77 Public purpose programs (107) (158) (124) 2019 GRC retroactive impacts — 56 111 Wildfire mitigation plan 178 93 12 Liability insurance premium 110 79 24 Other balancing accounts 207 61 70 Other regulatory assets (liabilities), net (2) 119 72 (153) Total SDG&E (1,299) (1,548) (1,746) SoCalGas: Deferred income taxes recoverable (refundable) in rates 44 (82) (203) Pension and other postretirement benefit plan obligations 51 417 400 Employee benefit costs 31 37 44 Removal obligations (627) (685) (728) Environmental costs 34 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (146) (56) (118) Safety and reliability 339 335 295 Public purpose programs (183) (253) (273) 2019 GRC retroactive impacts — 202 400 Liability insurance premium 16 7 4 Other balancing accounts 42 (65) (11) Other regulatory assets (liabilities), net (2) 142 75 (101) Total SoCalGas (257) (32) (251) Sempra Infrastructure: Deferred income taxes recoverable in rates 77 80 83 Other regulatory assets — — 6 Total Sempra $ (1,479) $ (1,500) $ (1,908) (1) At December 31, 2021, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $358, $139 and $108, respectively, and for SoCalGas was $410, $218 and $500, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.
Schedule of Regulatory Liabilities	We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2021 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (50) $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 125 22 (108) Pension and other postretirement benefit plan obligations (7) 50 103 Removal obligations (2,251) (2,121) (2,056) Environmental costs 62 56 45 Sunrise Powerlink fire mitigation 122 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 77 72 102 Gas transportation 49 35 22 Safety and reliability 67 67 77 Public purpose programs (107) (158) (124) 2019 GRC retroactive impacts — 56 111 Wildfire mitigation plan 178 93 12 Liability insurance premium 110 79 24 Other balancing accounts 207 61 70 Other regulatory assets (liabilities), net (2) 119 72 (153) Total SDG&E (1,299) (1,548) (1,746) SoCalGas: Deferred income taxes recoverable (refundable) in rates 44 (82) (203) Pension and other postretirement benefit plan obligations 51 417 400 Employee benefit costs 31 37 44 Removal obligations (627) (685) (728) Environmental costs 34 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (146) (56) (118) Safety and reliability 339 335 295 Public purpose programs (183) (253) (273) 2019 GRC retroactive impacts — 202 400 Liability insurance premium 16 7 4 Other balancing accounts 42 (65) (11) Other regulatory assets (liabilities), net (2) 142 75 (101) Total SoCalGas (257) (32) (251) Sempra Infrastructure: Deferred income taxes recoverable in rates 77 80 83 Other regulatory assets — — 6 Total Sempra $ (1,479) $ (1,500) $ (1,908) (1) At December 31, 2021, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $358, $139 and $108, respectively, and for SoCalGas was $410, $218 and $500, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.
Proposed Revenue Requirement	The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2021 2020 2019 Wildfire Fund asset: Current Prepaid Expenses $ 29 $ 29 $ 29 Noncurrent Wildfire Fund 331 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 $ 13 Noncurrent Deferred Credits and Other 64 75 86 Years ended December 31, 2021 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 29 $ 12 Impairment of Wildfire Fund asset Impairment Losses (1) 3 — — Accretion of Wildfire Fund obligation Operation and Maintenance 2 2 1 (1) Included in O&M for SDG&E. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 %

ACQUISTIONS, DIVESTITURES AND_2

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Schedule Of Assets Held for Sale and Deconsolidation of Subsidiaries Table	Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Years ended December 31, 2020 (1) 2019 Revenues $ 570 $ 1,614 Cost of sales (364) (1,012) Gain on sale of discontinued operations 2,899 — Operating expenses (66) (159) Interest and other (3) (11) Income before income taxes and equity earnings 3,036 432 Income tax expense (1,186) (72) Equity earnings — 3 Income from discontinued operations, net of income tax 1,850 363 Earnings attributable to noncontrolling interests (10) (35) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 (1) Results include activity until deconsolidation of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020 and post-closing adjustments related to the sales of these businesses. The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations. ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS (Dollars in millions) December 31, 2019 Cash and cash equivalents $ 74 Restricted cash (1) 1 Accounts receivable, net 303 Due from unconsolidated affiliates 2 Inventories 36 Other current assets 29 Current assets $ 445 Due from unconsolidated affiliates $ 54 Goodwill and other intangible assets 801 Property, plant and equipment, net 2,618 Other noncurrent assets 40 Noncurrent assets $ 3,513 Short-term debt $ 52 Accounts payable 201 Current portion of long-term debt and finance leases 85 Other current liabilities 106 Current liabilities $ 444 Long-term debt and finance leases $ 702 Deferred income taxes 284 Other noncurrent liabilities 66 Noncurrent liabilities $ 1,052 (1) Primarily represents funds held in accordance with Peruvian tax law.

INVESTMENTS IN UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2021
Investments [Abstract]
Equity Method Investments	We provide the carrying values of our investments and earnings (losses) on these investments in the following tables. EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) Percent ownership December 31, December 31, 2021 2020 2019 2021 2020 2019 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % 100 % $ 12,947 $ 12,440 $ 11,519 Sempra Texas Utilities: Sharyland Holdings (2) 50 50 50 $ 100 $ 102 $ 100 Sempra Infrastructure: Cameron LNG JV (3) 50.2 50.2 50.2 514 433 1,256 ESJ JV (4) — 50 50 — 34 39 IMG JV (5) 40 40 40 523 440 337 TAG JV (6) 50 50 50 388 378 365 Total other equity method investments 1,525 1,387 2,097 Other — 1 6 Total other investments $ 1,525 $ 1,388 $ 2,103 (1) The carrying value of our equity method investment is $2,844, $2,833 and $2,823 higher than the underlying equity in the net assets of the investee at December 31, 2021, 2020 and 2019, respectively, due to $2,868 of equity method goodwill and $69 in basis differences in AOCI, offset by $93, $104 and $114 at December 31, 2021, 2020 and 2019, respectively, due to a tax sharing liability to TTI under a tax sharing agreement. (2) The carrying value of our equity method investment is $42 higher than the underlying equity in the net assets of the investee due to equity method goodwill. (3) The carrying value of our equity method investment is $276, $259 and $263 higher than the underlying equity in the net assets of the investee at December 31, 2021, 2020 and 2019, respectively, primarily due to guarantees, which we discuss below, interest capitalized on the investment prior to the JV commencing its planned principal operations in August 2019 and amortization of guarantee fees and capitalized interest thereafter. (4 ) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. After the acquisition, ESJ is no longer accounted for as an equity method investment. The carrying value of our equity method investment is $12 higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019 due to the remeasurement of our retained investment to fair value in 2014. (5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees. (6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2021 2020 2019 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 5 $ 3 $ 2 Sempra Infrastructure: Cameron LNG JV (2) 559 391 24 Sempra Renewables: Wind assets — — 5 Parent and other: RBS Sempra Commodities 50 (100) — Other — — (1) 614 294 30 EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 617 577 526 Sempra Infrastructure: ESJ JV 2 5 2 IMG JV 83 103 9 TAG JV 27 36 13 729 721 550 Total $ 1,343 $ 1,015 $ 580 (1) We provide our ETR calculation in Note 8. (2) Includes $3 of basis differences in equity earnings related to AOCI in 2021. We disclose distributions received from our investments, by segment, in the table below. DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra Texas Utilities $ 688 $ 286 $ 246 Sempra Infrastructure 672 1,176 2 Sempra Renewables — — 1 Parent and other — — 7 Total $ 1,360 $ 1,462 $ 256
Schedule of Summarized Financial Information	We provide summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Year ended December 31, 2021 2020 2019 Operating revenues $ 4,764 $ 4,511 $ 4,347 Operating expense (3,397) (3,224) (3,135) Income from operations 1,367 1,287 1,212 Interest expense (413) (405) (375) Income tax expense (163) (146) (131) Net income 760 703 643 Noncontrolling interest held by TTI (152) (141) (129) Earnings attributable to Sempra (1) 608 562 514 At December 31, 2021 2020 2019 Current assets $ 1,039 $ 1,045 $ 913 Noncurrent assets 29,481 28,022 26,012 Current liabilities 2,220 1,120 1,626 Noncurrent liabilities 15,281 15,611 14,125 Noncontrolling interest held by TTI 2,916 2,737 2,473 We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings and RBS Sempra Commodities) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2021 (1) 2020 2019 (2) Gross revenues $ 2,721 $ 2,341 $ 798 Operating expense (719) (706) (372) Income from operations 2,002 1,635 426 Interest expense (548) (514) (401) Net income/Earnings (3) 1,388 1,132 85 At December 31, 2021 (1) 2020 2019 (2) Current assets $ 788 $ 1,035 $ 1,124 Noncurrent assets 14,686 15,304 15,039 Current liabilities 1,230 1,342 1,232 Noncurrent liabilities 11,807 12,863 11,438 (1) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. (2) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments. As of April 22, 2019, these wind assets and investments are no longer equity method investments. (3) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	COMMITTED LINES OF CREDIT (Dollars in millions) At December 31, 2021 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Available unused credit Sempra May 2024 $ 3,185 $ (1,240) $ — 1,945 Sempra May 2024 1,250 — — 1,250 SDG&E May 2024 1,500 (401) — 1,099 SoCalGas May 2024 750 (385) — 365 SI Partners November 2024 1,000 — — 1,000 IEnova September 2023 350 — (350) — IEnova February 2024 1,500 — (399) 1,101 Total $ 9,535 $ (2,026) $ (749) $ 6,760 FOREIGN UNCOMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2021 Borrower Expiration date of facility Borrowing denomination Total facility Amounts outstanding Available unused credit IEnova (1) September 2022 U.S. dollars $ 250 $ (250) $ — ECA LNG Phase 1 (2) August 2023 U.S. dollars or Mexican pesos 100 (63) 37 IEnova (3) October 2023 U.S. dollars 100 (8) 92 IEnova (4) October 2023 U.S. dollars or Mexican pesos 20 — 20 Total $ 470 $ (321) $ 149 (1) Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps. (2) Outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps. (3) Borrowings bear interest at a per annum rate equal to between 1-month and 6-month LIBOR plus 52 bps. (4) Borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing. UNCOMMITTED LETTERS OF CREDIT (Dollars in millions) December 31, 2021 Expiration date range Uncommitted letters of credit outstanding SDG&E January 2022 to May 2022 $ 15 SoCalGas March 2022 to November 2022 15 Sempra Infrastructure March 2022 to October 2043 473 Parent and other April 2022 to May 2023 179 Total $ 682 The weighted-average interest rates on the total short-term debt at December 31 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2021 2020 2019 Sempra 0.60 % 0.83 % 2.31 % SDG&E 0.65 — 1.97 SoCalGas 0.21 0.14 1.86
Schedule Of Long-term Debt	The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2021 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ — $ 350 $ 350 1.914% payable 2015 through February 2022 17 53 89 3.6% September 1, 2023 450 450 450 2.5% May 15, 2026 500 500 500 6% June 1, 2026 250 250 250 1.7% October 1, 2030 800 800 — 5.875% January and February 2034 (1) — — 176 5.35% May 15, 2035 250 250 250 6.125% September 15, 2037 250 250 250 4% May 1, 2039 (1) — — 75 6% June 1, 2039 300 300 300 5.35% May 15, 2040 250 250 250 4.5% August 15, 2040 500 500 500 3.95% November 15, 2041 250 250 250 4.3% April 1, 2042 250 250 250 3.75% June 1, 2047 400 400 400 4.15% May 15, 2048 400 400 400 4.1% June 15, 2049 400 400 400 3.32% April 15, 2050 400 400 — 2.95% August 15, 2051 750 — — 6,417 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) — 200 — Finance lease obligations: Purchased-power contracts 1,217 1,237 1,255 Other 57 39 15 1,274 1,476 1,270 7,691 7,529 6,410 Current portion of long-term debt (49) (611) (56) Unamortized discount on long-term debt (17) (13) (12) Unamortized debt issuance costs (44) (39) (36) Total SDG&E 7,581 6,866 6,306 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ 500 $ 500 $ 500 3.2% June 15, 2025 350 350 350 2.6% June 15, 2026 500 500 500 2.55% February 1, 2030 650 650 — 5.75% November 15, 2035 250 250 250 5.125% November 15, 2040 300 300 300 3.75% September 15, 2042 350 350 350 4.45% March 15, 2044 250 250 250 4.125% June 1, 2048 400 400 400 4.3% January 15, 2049 550 550 550 3.95% February 15, 2050 350 350 350 4,450 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.55% at December 31, 2021) September 14, 2023 (1) 300 300 — 1.875% Notes May 14, 2026 (1) 4 4 4 5.67% Notes January 18, 2028 (2) 5 5 5 Finance lease obligations 61 54 19 370 363 28 4,820 4,813 3,828 Current portion of long-term debt (11) (10) (6) Unamortized discount on long-term debt (7) (8) (7) Unamortized debt issuance costs (29) (32) (27) Total SoCalGas 4,773 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2021 2020 2019 Sempra: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 Sempra Infrastructure: Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 189 197 207 Loan at variable rates (2.93% at December 31, 2021) December 9, 2025 341 17 — Notes at 2.87% to 3.51% October 1, 2026 (1) — — 22 Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets (2) 154 196 237 3.75% Notes January 14, 2028 300 300 300 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — — 11 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets — 398 423 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 200 2.9% Loan November 15, 2034 (1) 241 241 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 100 — 4.875% Notes January 14, 2048 540 540 540 4.75% Notes January 15, 2051 800 800 — 8,923 11,247 12,298 Current portion of long-term debt (46) (919) (1,464) Unamortized discount on long-term debt (65) (55) (35) Unamortized debt issuance costs (98) (121) (108) Total other Sempra 8,714 10,152 10,691 Total Sempra $ 21,068 $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2021 2020 2019 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 6,058 8,258 10,358 Current portion of long-term debt — (850) (1,399) Unamortized discount on long-term debt (37) (32) (35) Unamortized debt issuance costs (52) (59) (68) Total long-term debt $ 5,969 $ 7,317 $ 8,856 (1) Callable long-term debt not subject to make-whole provisions.
Schedule of Maturities of Long-term Debt	MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Total 2022 $ 17 $ — $ 46 $ 63 2023 450 300 257 1,007 2024 — 500 48 548 2025 — 350 410 760 2026 750 500 74 1,324 Thereafter 5,200 3,109 8,088 16,397 Total $ 6,417 $ 4,759 $ 8,923 $ 20,099
Schedule Of Callable Long Term Debt	At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2021 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ — $ 304 $ 2,299 $ 2,603 Subject to make-whole provisions 6,417 4,450 6,470 17,337

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Income tax expense from continuing operations $ 99 $ 249 $ 315 Income from continuing operations before income taxes and equity earnings $ 219 $ 1,489 $ 1,734 Equity earnings, before income tax (1) 614 294 30 Pretax income $ 833 $ 1,783 $ 1,764 Effective income tax rate 12 % 14 % 18 % SDG&E: Income tax expense $ 201 $ 190 $ 171 Income before income taxes $ 1,020 $ 1,014 $ 945 Effective income tax rate 20 % 19 % 18 % SoCalGas: Income tax (benefit) expense $ (310) $ 96 $ 120 (Loss) income before income taxes $ (736) $ 601 $ 762 Effective income tax rate 42 % 16 % 16 % (1) We discuss how we recognize equity earnings in Note 6. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2021 2020 2019 Sempra: U.S. federal statutory income tax rate 21 % 21 % 21 % Outside basis differences 9 — — Utility depreciation 8 3 3 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (1) 5 2 3 Foreign exchange and inflation effects (2) 1 (3) 4 Valuation allowances 1 (1) — Tax credits — (1) (2) Excess deferred income taxes outside of ratemaking — — (4) Compensation-related items (1) (1) — Impairment losses (1) 1 — Noncontrolling interests (2) — — Allowance for equity funds used during construction (3) (1) (1) Amortization of excess deferred income taxes (3) (1) (1) Remeasurement of deferred taxes (4) — — State income taxes, net of federal income tax benefit (4) 1 2 Utility self-developed software expenditures (5) (3) (2) Utility repairs expenditures (9) (4) (3) Other, net (1) 1 (2) Effective income tax rate 12 % 14 % 18 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 5 5 6 Depreciation 3 3 3 Excess deferred income taxes outside of ratemaking — — (3) Self-developed software expenditures (1) (4) (3) Amortization of excess deferred income taxes (2) (1) (1) Allowance for equity funds used during construction (2) (2) (1) Repairs expenditures (4) (3) (3) Other, net — — (1) Effective income tax rate 20 % 19 % 18 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 11 2 4 Repairs expenditures 5 (7) (4) Self-developed software expenditures 5 (4) (2) Amortization of excess deferred income taxes 2 (1) (1) Allowance for equity funds used during construction 1 (1) (1) Nondeductible expenditures — 2 — Excess deferred income taxes outside of ratemaking — — (5) Depreciation (5) 5 4 Other, net 2 (1) — Effective income tax rate 42 % 16 % 16 % (1) Related to operations in Mexico. (2) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. We also recognize gains (losses) in Other Income (Expense), Net, on the Consolidated Statements of Operations from foreign currency derivatives that are partially hedging Sempra Infrastructure’s exposure to movements in the Mexican peso from its controlling interest in IEnova.
Schedule Of Geographic Components Of Income Before Income Taxes And Equity Earnings Of Certain Unconsolidated Subsidiaries	The table below presents the geographic components of pretax income. PRETAX INCOME (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: By geographic components: U.S. $ 346 $ 1,461 $ 1,191 Non-U.S. 487 322 573 Total (1) $ 833 $ 1,783 $ 1,764 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the calculation of pretax income.
Schedule Of Components Of Income Tax Expense	The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Current: U.S. state $ (6) $ (22) $ (14) Non-U.S. 183 112 140 Total 177 90 126 Deferred: U.S. federal (9) 157 87 U.S. state (37) 36 21 Non-U.S. (31) (34) 84 Total (77) 159 192 Deferred investment tax credits (1) — (3) Total income tax expense $ 99 $ 249 $ 315 SDG&E: Current: U.S. federal $ 35 $ 121 $ 35 U.S. state 13 34 31 Total 48 155 66 Deferred: U.S. federal 99 11 75 U.S. state 54 25 32 Total 153 36 107 Deferred investment tax credits — (1) (2) Total income tax expense $ 201 $ 190 $ 171 SoCalGas: Current: U.S. federal $ 134 $ 163 $ 8 U.S. state 50 45 24 Total 184 208 32 Deferred: U.S. federal (334) (85) 79 U.S. state (159) (28) 10 Total (493) (113) 89 Deferred investment tax credits (1) 1 (1) Total income tax (benefit) expense $ (310) $ 96 $ 120
Schedule Of Components Of Deferred Tax Assets And Liabilities	The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES – SEMPRA (Dollars in millions) December 31, 2021 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 5,230 $ 4,891 $ 4,052 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 47 46 153 Regulatory balancing accounts 538 587 468 Right-of-use assets – operating leases 160 144 131 Property taxes 52 51 44 Other deferred income tax liabilities 50 40 93 Total deferred income tax liabilities 6,077 5,759 4,941 Deferred income tax assets: Tax credits 1,135 1,161 1,136 Net operating losses 706 1,299 911 Postretirement benefits 30 162 200 Compensation-related items 164 169 161 Operating lease liabilities 140 125 131 Other deferred income tax assets 130 97 60 State income taxes 21 20 8 Bad debt allowance 33 35 4 Accrued expenses not yet deductible 575 130 52 Deferred income tax assets before valuation allowances 2,934 3,198 2,663 Less: valuation allowances 183 174 144 Total deferred income tax assets 2,751 3,024 2,519 Net deferred income tax liability (2) $ 3,326 $ 2,735 $ 2,422 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2021, 2020, and 2019, includes $151, $136, and $155, respectively, recorded as a noncurrent asset and $3,477, $2,871, and $2,577, respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES – SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2021 2020 2019 2021 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,970 $ 1,833 $ 1,735 $ 1,444 $ 1,322 $ 1,246 Regulatory balancing accounts 323 224 141 215 362 327 Right-of-use assets – operating leases 52 28 32 16 21 22 Property taxes 35 34 30 17 17 14 Other 1 2 14 1 1 1 Total deferred income tax liabilities 2,381 2,121 1,952 1,693 1,723 1,610 Deferred income tax assets: Tax credits 5 5 6 3 3 3 Postretirement benefits — 14 37 18 123 120 Compensation-related items 12 12 6 33 36 25 Operating lease liabilities 52 28 32 16 21 22 Bad debt allowance 16 18 3 15 15 1 State income taxes 4 8 7 12 11 8 Accrued expenses not yet deductible 16 14 9 539 93 15 Other 1 3 4 18 15 13 Total deferred income tax assets 106 102 104 654 317 207 Net deferred income tax liability $ 2,275 $ 2,019 $ 1,848 $ 1,039 $ 1,406 $ 1,403
Summary of Tax Credit Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2021 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,263 Indefinite General business tax credits (1) 436 2032 Foreign tax credits (2) 688 2024 U.S. state (2) : NOLs 2,938 2022 General business tax credits 6 2022 Non-U.S. (2) – NOLs 248 2022 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below.
Summary of Operating Loss Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2021 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,263 Indefinite General business tax credits (1) 436 2032 Foreign tax credits (2) 688 2024 U.S. state (2) : NOLs 2,938 2022 General business tax credits 6 2022 Non-U.S. (2) – NOLs 248 2022 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below.
Summary of Valuation Allowance	The following table provides the valuation allowances that we recorded against a portion of our total deferred income tax assets shown above in the “Deferred Income Taxes – Sempra” table. VALUATION ALLOWANCES (Dollars in millions) December 31, 2021 2020 2019 Sempra: U.S. federal $ 128 $ 118 $ 90 U.S. state 31 32 33 Non-U.S. 24 24 21 $ 183 $ 174 $ 144
Summary of Income Tax Contingencies	Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2021 2020 2019 Sempra: Balance at January 1 $ 99 $ 93 $ 119 Increase in prior period tax positions 3 3 5 Decrease in prior period tax positions (2) (1) — Increase in current period tax positions 204 4 2 Settlements with taxing authorities — — (32) Expiration of statutes of limitations — — (1) Balance at December 31 $ 304 $ 99 $ 93 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (105) $ (87) $ (81) increase the effective tax rate (1) 34 31 27 SDG&E: Balance at January 1 $ 13 $ 12 $ 11 Increase in prior period tax positions 1 1 1 Balance at December 31 $ 14 $ 13 $ 12 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (11) $ (10) $ (9) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 68 $ 64 $ 61 Increase in prior period tax positions 1 1 1 Increase in current period tax positions 3 3 2 Balance at December 31 $ 72 $ 68 $ 64 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (63) $ (59) $ (55) increase the effective tax rate (1) 33 30 26 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above.
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible	It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2021 2020 2019 Sempra: Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities $ 8 $ 8 $ 8 SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 6 $ 6 $ 6 SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 2 $ 2 $ 2

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Schedule Of Defined Benefit Plans, Change In Benefit Obligation And Fair Value Of Plan Assets	The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2021, 2020 and 2019, and a statement of the funded status at December 31, 2021, 2020 and 2019: PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 4,077 $ 3,768 $ 3,339 $ 989 $ 913 $ 868 Service cost 145 129 110 23 18 17 Interest cost 112 129 139 28 33 36 Contributions from plan participants — — — 21 22 21 Actuarial (gain) loss (76) 351 445 (53) 79 45 Plan amendments — — 5 — — — Benefit payments (98) (93) (93) (68) (74) (72) Settlements (303) (207) (177) — (2) (2) Net obligation at December 31 3,857 4,077 3,768 940 989 913 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 3,002 2,662 2,160 1,399 1,281 1,108 Actual return on plan assets 340 350 496 51 164 218 Employer contributions 241 290 276 5 8 8 Contributions from plan participants — — — 21 22 21 Benefit payments (98) (93) (93) (68) (74) (72) Settlements (303) (207) (177) — (2) (2) Fair value of plan assets at December 31 3,182 3,002 2,662 1,408 1,399 1,281 Funded status at December 31 $ (675) $ (1,075) (1,106) $ 468 $ 410 $ 368 Net recorded (liability) asset at December 31 $ (675) $ (1,075) (1,106) $ 468 $ 410 $ 368 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SDG&E: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 913 $ 895 $ 814 $ 193 $ 177 $ 170 Service cost 35 31 30 5 4 4 Interest cost 25 30 34 5 6 7 Contributions from plan participants — — — 7 8 7 Actuarial (gain) loss (2) 37 61 (3) 17 7 Plan amendments — — 3 — — — Benefit payments (17) (18) (18) (19) (20) (18) Settlements (69) (52) (39) — — — Transfer of liability from other plans — (10) 10 — 1 — Net obligation at December 31 885 913 895 188 193 177 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 819 739 600 213 197 172 Actual return on plan assets 73 94 135 (5) 26 36 Employer contributions 53 52 52 1 1 — Contributions from plan participants — — — 7 8 7 Benefit payments (17) (18) (18) (19) (20) (18) Settlements (69) (52) (39) — — — Transfer of assets from other plans — 4 9 — 1 — Fair value of plan assets at December 31 859 819 739 197 213 197 Funded status at December 31 $ (26) $ (94) (156) $ 9 $ 20 $ 20 Net recorded (liability) asset at December 31 $ (26) $ (94) (156) $ 9 $ 20 $ 20 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension benefits Other postretirement benefits (Dollars in millions) 2021 2020 2019 2021 2020 2019 SoCalGas: CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,829 $ 2,526 $ 2,148 $ 749 $ 688 $ 646 Service cost 97 86 68 17 14 12 Interest cost 78 88 91 22 25 27 Contributions from plan participants — — — 13 14 13 Actuarial (gain) loss (83) 282 345 (49) 57 39 Plan amendments — — 2 — — — Benefit payments (63) (60) (59) (46) (49) (49) Settlements (211) (105) (65) — — — Transfer of liability to other plans — 12 (4) — — — Net obligation at December 31 2,647 2,829 2,526 706 749 688 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,969 1,737 1,385 1,159 1,059 916 Actual return on plan assets 243 243 320 51 134 178 Employer contributions 157 152 152 1 1 1 Contributions from plan participants — — — 13 14 13 Benefit payments (63) (60) (59) (46) (49) (49) Settlements (211) (105) (65) — — — Transfer of assets from other plans — 2 4 — — — Fair value of plan assets at December 31 2,095 1,969 1,737 1,178 1,159 1,059 Funded status at December 31 $ (552) $ (860) $ (789) $ 472 $ 410 $ 371 Net recorded (liability) asset at December 31 $ (552) $ (860) $ (789) $ 472 $ 410 $ 371
Schedule Of Defined Benefit Plans, Amounts Recognized In Balance Sheet	The net (liability) asset is included in the following categories on the Consolidated Balance Sheets at December 31: PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Noncurrent assets $ 19 $ — $ — $ 481 $ 430 $ 391 Current liabilities (19) (35) (59) (1) (1) (3) Noncurrent liabilities (675) (1,040) (1,047) (12) (19) (20) Net recorded (liability) asset $ (675) $ (1,075) $ (1,106) $ 468 $ 410 $ 368 SDG&E: Noncurrent assets $ — $ — $ — $ 9 $ 20 $ 20 Current liabilities (1) (2) (3) — — — Noncurrent liabilities (25) (92) (153) — — — Net recorded (liability) asset $ (26) $ (94) $ (156) $ 9 $ 20 $ 20 SoCalGas: Noncurrent assets $ — $ — $ — $ 472 $ 410 $ 371 Current liabilities (1) (7) (4) — — — Noncurrent liabilities (551) (853) (785) — — — Net recorded (liability) asset $ (552) $ (860) $ (789) $ 472 $ 410 $ 371
Schedule Of Defined Benefit Plans, Amounts In Accumulated Other Comprehensive Income	Amounts recorded in AOCI at December 31, net of income tax effects and amounts recorded as regulatory assets, are as follows: AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra (1) : Net actuarial (loss) gain $ (86) $ (102) $ (113) $ 11 $ 8 $ 10 Prior service cost (8) (11) (14) — — — Total $ (94) $ (113) $ (127) $ 11 $ 8 $ 10 SDG&E: Net actuarial loss $ (9) $ (8) $ (9) Prior service cost (1) (2) (7) Total $ (10) $ (10) $ (16) SoCalGas: Net actuarial loss $ (15) $ (14) $ (7) Prior service cost (3) (4) (3) Total $ (18) $ (18) $ (10)
Schedule Of Defined Benefit Plans, Pension Plans With Benefit Obligations In Excess Of Plan Assets	The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2021 2020 2019 Sempra: Projected benefit obligation $ 2,612 $ 3,679 $ 3,578 Accumulated benefit obligation 2,277 3,265 3,229 Fair value of plan assets 2,095 2,788 2,662 SDG&E: Projected benefit obligation $ 887 $ 861 Accumulated benefit obligation 834 818 Fair value of plan assets 819 739 SoCalGas: Projected benefit obligation $ 2,612 $ 2,792 $ 2,505 Accumulated benefit obligation 2,277 2,431 2,208 Fair value of plan assets 2,095 1,969 1,737 We also have unfunded pension plans at Sempra, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans at December 31: OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) 2021 2020 2019 Sempra: Projected benefit obligation $ 178 $ 184 $ 190 Accumulated benefit obligation 139 146 158 SDG&E: Projected benefit obligation $ 26 $ 26 $ 34 Accumulated benefit obligation 22 22 27 SoCalGas: Projected benefit obligation $ 35 $ 37 $ 21 Accumulated benefit obligation 29 31 17 Sempra, SDG&E and SoCalGas each have a funded other postretirement benefit plan. At December 31, 2021, the assets for SDG&E’s and SoCalGas’ other postretirement benefit plans exceeded the plans’ obligations. The following table shows the obligations of funded other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2021 2020 2019 Sempra: Accumulated postretirement benefit obligation $ 34 $ 33 $ 32 Fair value of plan assets 33 27 25 We also have unfunded other postretirement benefit plans at Sempra. The following table shows the obligations of unfunded other postretirement benefit plans at December 31: OBLIGATIONS OF UNFUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2021 2020 2019 Sempra: Accumulated postretirement benefit obligation $ 12 $ 14 $ 16
Schedule of Net Periodic Costs and Amounts Recognized in OCI	The following tables provide the components of net periodic benefit cost and pretax amounts recognized in OCI for the years ended December 31: NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: NET PERIODIC BENEFIT COST Service cost $ 145 $ 129 $ 110 $ 23 $ 18 $ 17 Interest cost 112 129 139 28 33 36 Expected return on assets (173) (169) (144) (61) (55) (71) Amortization of: Prior service cost (credit) 11 12 12 (2) (2) — Actuarial loss (gain) 45 35 36 (9) (10) (10) Settlement charges 38 22 28 — — — Net periodic benefit cost (credit) 178 158 181 (21) (16) (28) Regulatory adjustment 57 91 77 21 16 29 Total expense recognized 235 249 258 — — 1 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net (gain) loss (5) 28 17 (4) 1 (3) Prior service cost — — 5 — — — Amortization of actuarial loss (8) (14) (13) — — — Amortization of prior service cost (4) (4) (3) — — — Settlements (7) (22) (28) — — — Total recognized in OCI (24) (12) (22) (4) 1 (3) Total recognized in net periodic benefit cost and OCI $ 211 $ 237 $ 236 $ (4) $ 1 $ (2) (1) Includes discontinued operations in 2020 and 2019. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SDG&E: NET PERIODIC BENEFIT COST Service cost $ 35 $ 31 $ 30 $ 5 $ 4 $ 4 Interest cost 25 30 34 5 6 7 Expected return on assets (50) (49) (38) (10) (10) (11) Amortization of: Prior service cost 1 2 3 — — 2 Actuarial loss (gain) 2 3 11 (2) (3) (2) Settlement charges 6 — — — — — Net periodic benefit cost (credit) 19 17 40 (2) (3) — Regulatory adjustment 34 38 14 2 3 — Total expense recognized 53 55 54 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 1 6 5 — — — Prior service cost — — 2 — — — Transfer of actuarial gain — (7) — — — — Transfer of prior service credit — (5) — — — — Amortization of actuarial loss — (1) — — — — Amortization of prior service cost (1) (1) (1) — — — Total recognized in OCI — (8) 6 — — — Total recognized in net periodic benefit cost and OCI $ 53 $ 47 $ 60 $ — $ — $ — NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 SoCalGas: NET PERIODIC BENEFIT COST Service cost $ 97 $ 86 $ 68 $ 17 $ 14 $ 12 Interest cost 78 88 91 22 25 27 Expected return on assets (113) (107) (94) (48) (43) (58) Amortization of: Prior service cost (credit) 8 8 8 (3) (2) (2) Actuarial loss (gain) 36 26 16 (7) (7) (8) Settlement charges 25 — — — — — Net periodic benefit cost (credit) 131 101 89 (19) (13) (29) Regulatory adjustment 23 53 63 19 13 29 Total expense recognized 154 154 152 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 2 6 2 — — — Prior service cost — — 3 — — — Transfer of actuarial loss (gain) — 5 (4) — — — Transfer of prior service cost (credit) — 3 (1) — — — Amortization of actuarial loss (1) (1) (1) — — — Amortization of prior service cost (1) (1) — — — — Total recognized in OCI — 12 (1) — — — Total recognized in net periodic benefit cost and OCI $ 154 $ 166 $ 151 $ — $ — $ —
Schedule of Assumptions Used	The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Discount rate 3.04 % 2.78 % 3.49 % 3.04 % 2.88 % 3.54 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 2.99 % 2.73 % 3.44 % 3.05 % 2.85 % 3.55 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 1.62 2.28 Rate of compensation increase 3.50-10.00 2.70-10.00 2.70-10.00 3.50-10.00 2.70-10.00 2.70-10.00 SoCalGas: Discount rate 3.04 % 2.79 % 3.50 % 3.05 % 2.90 % 3.55 % Interest crediting rate (1)(2) 1.94 1.62 2.28 1.94 % 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2021 2020 2019 2021 2020 2019 Sempra: Discount rate 2.78 % 3.49 % 4.29 % 2.88 % 3.54 % 4.29 % Expected return on plan assets 6.47 7.00 7.00 4.76 4.64 6.48 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 SDG&E: Discount rate 2.73 % 3.44 % 4.29 % 2.85 % 3.55 % 4.30 % Expected return on plan assets 6.25 7.00 7.00 4.81 5.51 6.92 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 SoCalGas: Discount rate 2.79 % 3.50 % 4.30 % 2.90 % 3.55 % 4.30 % Expected return on plan assets 6.75 7.00 7.00 4.70 4.41 6.38 Interest crediting rate (1)(2) 1.62 2.28 3.36 1.62 2.28 3.36 Rate of compensation increase 2.70-10.00 2.70-10.00 2.00-10.00 2.70-10.00 2.70-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2021 2020 2019 2021 2020 2019 Health care cost trend rate assumed for next year 6.00 % 6.00 % 6.25 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 2022 2022 2022
Schedule of Health Care Cost Trend Rates	Assumed health care cost trend rates have a significant effect on the amounts that Sempra, SDG&E and SoCalGas report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans: ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2021 2020 2019 2021 2020 2019 Health care cost trend rate assumed for next year 6.00 % 6.00 % 6.25 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 2022 2022 2022
Schedule Of Defined Benefit Plans, Fair Value Of Plan Assets By Level In Fair Value Hierarchy	The fair values of our pension plan assets by asset category are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Total Sempra: Cash and cash equivalents $ 18 $ — $ 18 Equity securities: Domestic 844 5 849 International 384 1 385 Registered investment companies: Domestic 204 21 225 International 33 — 33 Fixed income securities: Domestic government and government agencies 463 24 487 International government bonds — 11 11 Domestic corporate bonds — 413 413 International corporate bonds — 65 65 Other 1 — 1 Total investment assets in the fair value hierarchy $ 1,947 $ 540 2,487 Accounts receivable/payable, net (20) Investments measured at NAV: Common/collective trusts 657 Venture capital funds and real estate funds 58 Total investment assets $ 3,182 SDG&E’s proportionate share of investment assets $ 859 SoCalGas’ proportionate share of investment assets $ 2,095 Fair value at December 31, 2020 Level 1 Level 2 Total Sempra: Cash and cash equivalents $ 7 $ — $ 7 Equity securities: Domestic 931 — 931 International 563 — 563 Registered investment companies: Domestic 151 37 188 International 32 — 32 Fixed income securities: Domestic government and government agencies 238 34 272 International government bonds — 13 13 Domestic corporate bonds — 418 418 International corporate bonds — 61 61 Other 2 (1) 1 Total investment assets in the fair value hierarchy $ 1,924 $ 562 2,486 Accounts receivable/payable, net 13 Investments measured at NAV: Common/collective trusts 493 Venture capital funds and real estate funds 10 Total investment assets $ 3,002 SDG&E’s proportionate share of investment assets $ 819 SoCalGas’ proportionate share of investment assets $ 1,969 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Total Sempra: Cash and cash equivalents $ 17 $ — $ 17 Equity securities: Domestic 923 — 923 International 555 1 556 Registered investment companies: Domestic 93 2 95 International 3 — 3 Fixed income securities: Domestic government and government agencies 228 39 267 International government bonds — 9 9 Domestic corporate bonds — 346 346 International corporate bonds — 62 62 Total investment assets in the fair value hierarchy $ 1,819 $ 459 2,278 Accounts receivable/payable, net (38) Investments measured at NAV: Common/collective trusts 417 Venture capital funds and real estate funds 5 Total investment assets $ 2,662 SDG&E’s proportionate share of investment assets $ 739 SoCalGas’ proportionate share of investment assets $ 1,737 The fair values by asset category of the PBOP plan assets held in the pension master trust and in the additional trusts for SoCalGas’ PBOP plans and SDG&E’s PBOP plan trusts are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 16 $ — $ 16 International 7 — 7 Registered investment companies: Domestic 82 1 83 International 9 — 9 Fixed income securities: Domestic government and government agencies 24 1 25 Domestic corporate bonds — 8 8 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 138 11 149 Accounts receivable/payable, net (1) Investments measured at NAV – Common/collective trusts 49 Total investment assets 197 SoCalGas: Cash and cash equivalents 2 — 2 Equity securities: Domestic 83 1 84 International 37 — 37 Registered investment companies: Domestic 74 73 147 International 3 — 3 Fixed income securities: Domestic government and government agencies 241 17 258 International government bonds 1 11 12 Domestic corporate bonds — 337 337 International corporate bonds — 49 49 Total investment assets in the fair value hierarchy 441 488 929 Accounts receivable/payable, net (1) Investments measured at NAV: Common/collective trusts 244 Venture capital funds and real estate funds 6 Total investment assets 1,178 Other Sempra: Equity securities: Domestic 9 — 9 International 6 — 6 Registered investment companies – Domestic 2 — 2 Fixed income securities: Domestic government and government agencies 2 1 3 Domestic corporate bonds — 4 4 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 19 6 25 Investments measured at NAV: Common/collective trusts 7 Venture capital funds and real estate funds 1 Total other Sempra investment assets 33 Total Sempra investment assets in the fair value hierarchy $ 598 $ 505 Total Sempra investment assets $ 1,408 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2020 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 17 $ — $ 17 International 11 — 11 Registered investment companies: Domestic 69 7 76 International 11 — 11 Fixed income securities: Domestic government and government agencies 38 2 40 Domestic corporate bonds — 8 8 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 146 18 164 Accounts receivable/payable, net (2) Investments measured at NAV – Common/collective trusts 51 Total investment assets 213 SoCalGas: Cash and cash equivalents 1 — 1 Equity securities: Domestic 76 — 76 International 46 — 46 Registered investment companies: Domestic 58 81 139 International 3 — 3 Fixed income securities: Domestic government and government agencies 273 25 298 International government bonds 1 14 15 Domestic corporate bonds — 349 349 International corporate bonds — 42 42 Derivative financial instruments 1 — 1 Total investment assets in the fair value hierarchy 459 511 970 Investments measured at NAV: Common/collective trusts 188 Venture capital funds and real estate funds 1 Total investment assets 1,159 Other Sempra: Equity securities: Domestic 10 — 10 International 6 — 6 Registered investment companies – Domestic 1 (1) — Fixed income securities: Domestic government and government agencies 2 — 2 Domestic corporate bonds — 4 4 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 19 4 23 Investments measured at NAV – Common/collective trusts 4 Total other Sempra investment assets 27 Total Sempra investment assets in the fair value hierarchy $ 624 $ 533 Total Sempra investment assets $ 1,399 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 21 $ — $ 21 International 13 — 13 Registered investment companies: Domestic 57 8 65 International 11 — 11 Fixed income securities: Domestic government and government agencies 32 1 33 Domestic corporate bonds — 8 8 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 134 18 152 Accounts receivable/payable, net (2) Investments measured at NAV – Common/collective trusts 47 Total investment assets 197 SoCalGas: Cash and cash equivalents 3 — 3 Equity securities: Domestic 78 — 78 International 48 — 48 Registered investment companies – Domestic 52 75 127 Fixed income securities: Domestic government and government agencies 267 21 288 International government bonds 1 10 11 Domestic corporate bonds — 309 309 International corporate bonds — 40 40 Derivative financial instruments 3 — 3 Total investment assets in the fair value hierarchy 452 455 907 Accounts receivable/payable, net (5) Investments measured at NAV – Common/collective trusts 157 Total investment assets 1,059 Other Sempra: Equity securities: Domestic 9 — 9 International 4 — 4 Fixed income securities: Domestic government and government agencies 3 1 4 Domestic corporate bonds — 3 3 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 16 5 21 Investments measured at NAV – Common/collective trusts 4 Total other Sempra investment assets 25 Total Sempra investment assets in the fair value hierarchy $ 602 $ 478 Total Sempra investment assets $ 1,281
Schedule Of Defined Benefit Plans, Estimated Future Employer Contributions In Next Fiscal Year	We expect to contribute the following amounts to our pension and PBOP plans in 2022: EXPECTED CONTRIBUTIONS (Dollars in millions) Sempra SDG&E SoCalGas Pension plans $ 231 $ 52 $ 152 Other postretirement benefit plans 5 1 1
Schedule of Expected Benefit Payments	The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets. EXPECTED BENEFIT PAYMENTS (Dollars in millions) Sempra SDG&E SoCalGas Pension benefits Other postretirement benefits Pension benefits Other postretirement benefits Pension benefits Other postretirement benefits 2022 $ 276 $ 46 $ 71 $ 9 $ 171 $ 33 2023 261 46 69 10 163 33 2024 253 46 66 10 158 33 2025 244 46 65 10 156 33 2026 240 48 59 10 153 33 2027-2031 1,122 226 275 48 725 166
Schedule Of Defined Benefit Plans Contributions	Employer contributions to the savings plans were as follows: EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS (Dollars in millions) 2021 2020 2019 Sempra $ 52 $ 47 $ 44 SDG&E 18 16 15 SoCalGas 28 25 24

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Schedule Of Share-based Compensation Expense	Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra: Share-based compensation expense, before income taxes (1) $ 58 $ 62 $ 66 Income tax benefit (1) (16) (17) (18) $ 42 $ 45 $ 48 Capitalized share-based compensation cost $ 9 $ 11 $ 11 Excess income tax (benefit) deficiency $ (9) $ (19) $ 4 SDG&E: Share-based compensation expense, before income taxes $ 10 $ 11 $ 10 Income tax benefit (3) (3) (3) $ 7 $ 8 $ 7 Capitalized share-based compensation cost $ 5 $ 7 $ 6 Excess income tax (benefit) deficiency $ (1) $ (3) $ 1 SoCalGas: Share-based compensation expense, before income taxes $ 14 $ 14 $ 15 Income tax benefit (4) (4) (4) $ 10 $ 10 $ 11 Capitalized share-based compensation cost $ 4 $ 4 $ 5 Excess income tax (benefit) deficiency $ (1) $ (3) $ 1
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	To calculate this fair value, we used the Black-Scholes model with the following weighted-average assumptions: KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Years ended December 31, 2021 2020 2019 Sempra: Stock price volatility 26.57 % 18.78 % 18.63 % Expected term 5.36 years 5.34 years 5.34 years Risk-free rate of return 0.41 % 1.68 % 2.49 % Annual dividend yield 3.38 % 2.60 % 3.35 %
Schedule Of Non-qualified Stock Options	The following table shows a summary of nonqualified stock options at December 31, 2021 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value (in millions) Sempra: Outstanding at January 1, 2021 365,395 $ 120.93 Granted 222,620 $ 123.80 Exercised (50,671) $ 106.76 Outstanding at December 31, 2021 537,344 $ 123.45 8.06 $ 5 Vested or expected to vest at December 31, 2021 537,344 $ 123.45 8.06 $ 5 Exercisable at December 31, 2021 152,189 $ 118.10 7.27 $ 2
Schedule Of Restricted Stock Awards And Units Valuation Assumptions	Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2021 2020 2019 Sempra: Stock price volatility 33.39 % 16.35 % 17.74 % Risk-free rate of return 0.16 % 1.55 % 2.46 %
Schedule Of Restricted Stock Units	The following table shows a summary of RSUs at December 31, 2021 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based restricted stock units Service-based restricted stock units Units Weighted- average grant-date fair value Units Weighted- average grant-date fair value Sempra: Nonvested at January 1, 2021 893,961 $ 121.61 343,577 $ 121.59 Granted 323,889 $ 133.03 143,980 $ 124.84 Vested (317,128) $ 105.03 (202,352) $ 116.28 Forfeited (29,945) $ 131.55 (7,905) $ 161.49 Nonvested at December 31, 2021 (1) 870,777 $ 131.64 277,300 $ 127.54 Expected to vest at December 31, 2021 854,697 $ 131.47 271,197 $ 127.47 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra exceeds target performance conditions.

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Volumes Table	The following table summarizes net energy derivative volumes. NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) December 31, Commodity Unit of measure 2021 2020 2019 Sempra: Natural gas MMBtu 184 189 231 Electricity MWh 1 1 2 Congestion revenue rights MWh 45 43 48 SDG&E: Natural gas MMBtu 7 16 37 Electricity MWh 1 1 2 Congestion revenue rights MWh 45 43 48 SoCalGas: Natural gas MMBtu 201 185 201
Notional Amounts Of Interest Rate Derivatives Table	The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments, at December 31: INTEREST RATE DERIVATIVES (Dollars in millions) 2021 2020 2019 Notional debt Maturities Notional debt Maturities Notional debt Maturities Sempra: Cash flow hedges $ 462 2022-2034 $ 1,486 2021-2034 $ 1,445 2020-2034 The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments, at December 31. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) 2021 2020 2019 Notional amount Maturities Notional amount Maturities Notional amount Maturities Sempra: Cross-currency swaps $ 306 2022-2023 $ 306 2021-2023 $ 306 2020-2023 Other foreign currency derivatives 106 2022-2023 1,764 2021-2022 1,796 2020-2021
Derivative Instruments on the Consolidated Balance Sheet Table	DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2021 Other current Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 6 $ (6) $ (2) Foreign exchange instruments 1 1 (1) — Interest rate and foreign exchange instruments — — (1) (130) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 136 11 (122) (10) Associated offsetting commodity contracts (93) (8) 93 8 Commodity contracts subject to rate recovery 38 52 (58) — Associated offsetting commodity contracts (8) — 8 — Net amounts presented on the balance sheet 74 62 (87) (134) Additional cash collateral for commodity contracts not subject to rate recovery 58 — — — Additional cash collateral for commodity contracts subject to rate recovery 46 — — — Total (1) $ 178 $ 62 $ (87) $ (134) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 34 $ 52 $ (20) $ — Associated offsetting commodity contracts (5) — 5 — Net amounts presented on the balance sheet 29 52 (15) — Additional cash collateral for commodity contracts subject to rate recovery 28 — — — Total (1) $ 57 $ 52 $ (15) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ — $ (38) $ — Associated offsetting commodity contracts (3) — 3 — Net amounts presented on the balance sheet 1 — (35) — Additional cash collateral for commodity contracts subject to rate recovery 18 — — — Total $ 19 $ — $ (35) $ — (1) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2020 Other current Other long-term assets Other current Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 1 $ (16) $ (31) Foreign exchange instruments — — (9) (2) Interest rate and foreign exchange instruments — — (1) (127) Derivatives not designated as hedging instruments: Foreign exchange instruments 24 — — — Commodity contracts not subject to rate recovery 82 17 (95) (16) Associated offsetting commodity contracts (82) (13) 82 13 Commodity contracts subject to rate recovery 35 95 (35) (25) Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 57 100 (72) (188) Additional cash collateral for commodity contracts not subject to rate recovery 21 — — — Additional cash collateral for commodity contracts subject to rate recovery 30 — — — Total (1) $ 108 $ 100 $ (72) $ (188) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 32 $ 95 $ (28) $ (25) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 31 95 (27) (25) Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (1) $ 55 $ 95 $ (27) $ (25) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (7) $ — Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 2 — (6) — Additional cash collateral for commodity contracts subject to rate recovery 6 — — — Total $ 8 $ — $ (6) $ — (1) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2019 Other current Other long-term assets Other current Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ — $ 3 $ (11) $ (17) Foreign exchange instruments — — (6) (1) Interest rate and foreign exchange instruments — — — (122) Derivatives not designated as hedging instruments: Foreign exchange instruments 41 — (20) — Associated offsetting foreign exchange instruments (20) — 20 — Commodity contracts not subject to rate recovery 34 11 (41) (10) Associated offsetting commodity contracts (32) (2) 32 2 Commodity contracts subject to rate recovery 41 76 (47) (47) Associated offsetting commodity contracts (6) (3) 6 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 58 85 (53) (192) Additional cash collateral for commodity contracts not subject to rate recovery 43 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (1) $ 126 $ 85 $ (53) $ (192) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 30 $ 76 $ (41) $ (47) Associated offsetting commodity contracts (4) (3) 4 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 26 73 (23) (44) Additional cash collateral for commodity contracts subject to rate recovery 16 — — — Total (1) $ 42 $ 73 $ (23) $ (44) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 11 $ — $ (6) $ — Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 9 — (4) — Additional cash collateral for commodity contracts subject to rate recovery 9 — — — Total $ 18 $ — $ (4) $ — (1) Normal purchase contracts previously measured at fair value are excluded.
Cash Flow Hedge Impact on the Consolidated Statements Of Operations Table	The following table includes the effects of derivative instruments designated as cash flow hedges on the Consolidated Statements of Operations and in OCI and AOCI. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax (loss) gain reclassified Years ended December 31, Years ended December 31, 2021 2020 2019 Location 2021 2020 2019 Sempra: Interest rate instruments $ — $ — $ — Gain (Loss) on Sale of Assets $ — $ — $ (10) Interest rate instruments (1) 29 (34) (24) Interest Expense (1) (11) (10) (3) Interest rate instruments 71 (185) (164) Equity Earnings (2) (73) (46) (3) Foreign exchange instruments 11 (4) (8) Revenues: Energy- Related Businesses (1) 1 (2) Foreign exchange instruments 8 (3) (10) Equity Earnings (2) — — (2) Interest rate and foreign exchange instruments (4) (6) 19 Interest Expense (1) (1) — Other Income (Expense), Net (6) (11) 9 Total $ 115 $ (232) $ (187) $ (92) $ (67) $ (11) SDG&E: Interest rate instruments (1) $ — $ — $ (1) Interest Expense (1) $ — $ — $ (3) SoCalGas: Interest rate instruments $ — $ — $ — Interest Expense $ — $ — $ (1) (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. In August 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps. (2) Equity earnings at our foreign equity method investees are recognized after tax.
Undesignated Derivative Impact on the Consolidated Statements of Operations	The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Years ended December 31, Location 2021 2020 2019 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ (203) $ 17 $ 12 Commodity contracts subject to rate recovery Cost of Natural Gas (25) (7) 3 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 31 88 (140) Foreign exchange instruments Other Income (Expense), Net (22) (56) 25 Total $ (219) $ 42 $ (100) SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 31 $ 88 $ (140) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (25) $ (7) $ 3

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 13 $ (10) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 8 — 56 Municipal bonds — 321 — 321 Other securities — 260 — 260 Total debt securities 48 589 — 637 Total nuclear decommissioning trusts (1) 419 585 — 1,004 Short-term investments held in Rabbi Trust 81 — — 81 Interest rate instruments — 6 — 6 Foreign exchange instruments — 2 — 2 Commodity contracts not subject to rate recovery — 46 — 46 Effect of netting and allocation of collateral (2) 58 — — 58 Commodity contracts subject to rate recovery 12 1 69 82 Effect of netting and allocation of collateral (2) 31 9 6 46 Support Agreement, net of related guarantee fees — — 7 7 Total $ 601 $ 649 $ 82 $ 1,332 Liabilities: Interest rate instruments $ — $ 8 $ — $ 8 Foreign exchange instruments — 1 — 1 Interest rate and foreign exchange instruments — 131 — 131 Commodity contracts not subject to rate recovery — 31 — 31 Commodity contracts subject to rate recovery — 35 15 50 Total $ — $ 206 $ 15 $ 221 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 9 $ (6) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 408 620 — 1,028 Short-term investments held in Rabbi Trust 61 — — 61 Interest rate instruments — 1 — 1 Foreign exchange instruments — 24 — 24 Commodity contracts not subject to rate recovery — 4 — 4 Effect of netting and allocation of collateral (2) 21 — — 21 Commodity contracts subject to rate recovery 6 1 121 128 Effect of netting and allocation of collateral (2) 19 5 6 30 Support Agreement, net of related guarantee fees — — 7 7 Total $ 515 $ 655 $ 134 $ 1,304 Liabilities: Interest rate instruments $ — $ 47 $ — $ 47 Foreign exchange instruments — 11 — 11 Interest rate and foreign exchange instruments — 128 — 128 Commodity contracts not subject to rate recovery — 16 — 16 Commodity contracts subject to rate recovery — 6 52 58 Support Agreement, net of related guarantee fees — — 4 4 Total $ — $ 208 $ 56 $ 264 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 14 $ 2 $ — $ 16 Equity securities 503 6 — 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 563 527 — 1,090 Short-term investments held in Rabbi Trust 66 — — 66 Interest rate instruments — 3 — 3 Foreign exchange instruments — 21 — 21 Commodity contracts not subject to rate recovery — 11 — 11 Effect of netting and allocation of collateral (2) 43 — — 43 Commodity contracts subject to rate recovery 5 8 95 108 Effect of netting and allocation of collateral (2) 11 8 6 25 Total $ 688 $ 578 $ 101 $ 1,367 Liabilities: Interest rate instruments $ — $ 28 $ — $ 28 Foreign exchange instruments — 7 — 7 Interest rate and foreign exchange instruments — 122 — 122 Commodity contracts not subject to rate recovery — 17 — 17 Commodity contracts subject to rate recovery 14 4 67 85 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 178 $ 67 $ 245 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 13 $ (10) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 8 — 56 Municipal bonds — 321 — 321 Other securities — 260 — 260 Total debt securities 48 589 — 637 Total nuclear decommissioning trusts (1) 419 585 — 1,004 Commodity contracts subject to rate recovery 12 — 69 81 Effect of netting and allocation of collateral (2) 22 — 6 28 Total $ 453 $ 585 $ 75 $ 1,113 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 15 $ 15 Total $ — $ — $ 15 $ 15 Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 9 $ (6) $ — $ 3 Equity securities 358 6 — 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 408 620 — 1,028 Commodity contracts subject to rate recovery 5 — 121 126 Effect of netting and allocation of collateral (2) 18 — 6 24 Total $ 431 $ 620 $ 127 $ 1,178 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 52 $ 52 Total $ — $ — $ 52 $ 52 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 14 $ 2 $ — $ 16 Equity securities 503 6 — 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 563 527 — 1,090 Commodity contracts subject to rate recovery 1 3 95 99 Effect of netting and allocation of collateral (2) 10 — 6 16 Total $ 574 $ 530 $ 101 $ 1,205 Liabilities: Commodity contracts subject to rate recovery $ 14 $ — $ 67 $ 81 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ — $ 67 $ 67 (1) Excludes receivables (payables), net. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2021 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Effect of netting and allocation of collateral (1) 9 9 — 18 Total $ 9 $ 10 $ — $ 19 Liabilities: Commodity contracts subject to rate recovery $ — $ 35 $ — $ 35 Total $ — $ 35 $ — $ 35 Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 1 $ — $ 2 Effect of netting and allocation of collateral (1) 1 5 — 6 Total $ 2 $ 6 $ — $ 8 Liabilities: Commodity contracts subject to rate recovery $ — $ 6 $ — $ 6 Total $ — $ 6 $ — $ 6 Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 4 $ 5 $ — $ 9 Effect of netting and allocation of collateral (1) 1 8 — 9 Total $ 5 $ 13 $ — $ 18 Liabilities: Commodity contracts subject to rate recovery $ — $ 4 $ — $ 4 Total $ — $ 4 $ — $ 4 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
Recurring Fair Value Measures Level 3 Rollforward Table	The table below sets forth reconciliations of changes in the fair value of CRRs and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) Years ended December 31, 2021 2020 2019 Balance at January 1 $ 69 $ 28 $ 179 Realized and unrealized (losses) gains (50) 19 (184) Allocated transmission instruments 3 6 6 Settlements 32 16 27 Balance at December 31 $ 54 $ 69 $ 28 Change in unrealized (losses) gains relating to instruments still held at December 31 $ (16) $ 34 $ (139) (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements. The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra. LEVEL 3 RECONCILIATIONS (Dollars in millions) Years ended December 31, 2021 2020 Balance at January 1 $ 3 $ — Realized and unrealized gains (1) 11 6 Settlements (7) (3) Balance at December 31 (2) $ 7 $ 3 Change in unrealized gains relating to instruments still held at December 31 $ 11 $ 3 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations. (2) Balances at December 31, 2021 and 2020 include $7 and $7, respectively, in Other Current Assets, offset by a negligible amount and $4, respectively, in Deferred Credits and Other on Sempra’s Consolidated Balance Sheets.
Schedule of Auction Price Inputs	For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below: CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2022 $ (3.67) to $ 6.96 $ (0.70) 2021 (1.81) to 14.11 (0.12) 2020 (3.77) to 6.03 (1.58) LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2021 $ 24.10 to $ 105.00 $ 53.57 2020 19.60 to 78.10 39.71 2019 21.00 to 61.15 37.92
Fair Value of Financial Instruments Table	The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value amount Level 1 Level 2 Level 3 Total December 31, 2021 Sempra: Long-term note receivable (1) $ 300 $ — $ — $ 327 $ 327 Long-term amounts due from unconsolidated affiliates (2) 640 — 642 — 642 Long-term amounts due to unconsolidated affiliates 287 — 295 — 295 Total long-term debt (3) 20,099 — 22,126 — 22,126 SDG&E: Total long-term debt (4) $ 6,417 $ — $ 7,236 $ — $ 7,236 SoCalGas: Total long-term debt (5) $ 4,759 $ — $ 5,367 $ — $ 5,367 December 31, 2020 Sempra: Long-term amounts due from unconsolidated affiliates (2) $ 786 $ — $ 817 $ — $ 817 Long-term amounts due to unconsolidated affiliates 275 — 266 — 266 Total long-term debt (3) 22,259 — 25,478 — 25,478 SDG&E: Total long-term debt (4) $ 6,253 $ — $ 7,384 $ — $ 7,384 SoCalGas: Total long-term debt (5) $ 4,759 $ — $ 5,655 $ — $ 5,655 December 31, 2019 Sempra: Long-term amounts due from unconsolidated affiliates $ 742 $ — $ 759 $ — $ 759 Long-term amounts due to unconsolidated affiliates 195 — 184 — 184 Total long-term debt (3) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (4) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (5) $ 3,809 $ — $ 4,189 $ — $ 4,189 (1) Before allowances for credit losses of $8 and excluding transaction costs of $5 at December 31, 2021. (2) Before allowances for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively. Includes $2 and $3 of accrued interest receivable at December 31, 2021 and 2020, respectively, in Due From Unconsolidated Affiliate – Current. (3) Before reductions of unamortized discount and debt issuance costs of $260, $268 and $225 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,335, $1,330 and $1,289 at December 31, 2021 and 2020 and 2019, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $61, $52 and $48 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,274, $1,276 and $1,270 at December 31, 2021, 2020 and 2019, respectively. (5) Before reductions of unamortized discount and debt issuance costs of $36, $40 and $34 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $61, $54 and $19 at December 31, 2021, 2020 and 2019, respectively.

PREFERRED STOCK (Tables)

PREFERRED STOCK (Tables)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Schedule Of Preferred Stock	The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2021 2020 2019 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 19 SoCalGas - Total preferred stock 22 22 22 Less: 50,970 shares of the 6% Series outstanding owned by PE (2) (2) (2) Sempra - Total preferred stock of subsidiary $ 20 $ 20 $ 20

SEMPRA - SHAREHOLDERS' EQUITY_2

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share Computations	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2021 2020 2019 Sempra: Numerator for continuing operations: Income from continuing operations, net of income tax $ 1,463 $ 2,255 $ 1,999 Earnings attributable to noncontrolling interests (145) (162) (129) Preferred dividends (63) (168) (142) Preferred dividends of subsidiary (1) (1) (1) Earnings from continuing operations attributable to common shares $ 1,254 $ 1,924 $ 1,727 Numerator for discontinued operations: Income from discontinued operations, net of income tax $ — $ 1,850 $ 363 Earnings attributable to noncontrolling interests — (10) (35) Earnings from discontinued operations attributable to common shares $ — $ 1,840 $ 328 Numerator for earnings: Earnings attributable to common shares $ 1,254 $ 3,764 $ 2,055 Denominator: Weighted-average common shares outstanding for basic EPS (1) 311,755 291,077 277,904 Dilutive effect of stock options and RSUs (2) 752 1,175 1,585 Dilutive effect of common shares sold forward — — 2,544 Dilutive effect of mandatory convertible preferred stock 529 — — Weighted-average common shares outstanding for diluted EPS 313,036 292,252 282,033 Basic EPS: Earnings from continuing operations $ 4.03 $ 6.61 $ 6.22 Earnings from discontinued operations $ — $ 6.32 $ 1.18 Earnings $ 4.03 $ 12.93 $ 7.40 Diluted EPS: Earnings from continuing operations $ 4.01 $ 6.58 $ 6.13 Earnings from discontinued operations $ — $ 6.30 $ 1.16 Earnings $ 4.01 $ 12.88 $ 7.29 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 453 in 2021, 537 in 2020 and 617 in 2019. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued. (2)
Schedule Of Common Stock Activity	The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY Years ended December 31, 2021 2020 2019 Sempra: Common shares outstanding, January 1 288,470,244 291,712,925 273,769,513 Conversion of mandatory convertible preferred stock 18,037,745 — — Shares issued in IEnova exchange offer 12,306,777 — — Shares issued under forward sale agreements — — 16,906,185 RSUs vesting (1) 686,916 896,839 463,012 Stock options exercised 50,671 4,400 52,540 Savings plan issuance — 201,431 475,774 Common stock investment plan (2) — 42,955 199,253 Issuance of RSUs held in our Deferred Compensation Plan 102,238 103,552 59,470 Shares repurchased (3) (2,734,809) (4,491,858) (212,822) Common shares outstanding, December 31 316,919,782 288,470,244 291,712,925 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) In 2021 and 2020, includes shares repurchased under the repurchase programs that we discuss above. Generally, we purchase shares of our common stock or units from LTIP participants who elect to sell to us a sufficient number of vested RSUs to meet minimum statutory tax withholding requirements.

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Schedule of Nuclear Decommissioning Trusts	The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 12. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated At December 31, 2021: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 56 $ — $ — $ 56 Municipal bonds (2) 309 13 (1) 321 Other securities (3) 255 7 (2) 260 Total debt securities 620 20 (3) 637 Equity securities 104 262 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net 8 — — 8 Total $ 735 $ 282 $ (5) $ 1,012 At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 64 $ 1 $ — $ 65 Municipal bonds 308 18 — 326 Other securities 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Short-term investments, primarily cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Short-term investments, primarily cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2052. (2) Maturity dates are 2022-2056. (3) Maturity dates are 2022-2072.
Schedule of Securities Sold	The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Proceeds from sales $ 961 $ 1,439 $ 914 Gross realized gains 67 156 24 Gross realized losses (5) (17) (5)

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Schedule of Leases Statement of Financial Position	Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below. LESSEE INFORMATION ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) Sempra SDG&E SoCalGas December 31, 2021 2020 2019 2021 2020 2019 2021 2020 2019 ROU assets: Operating leases: ROU assets $ 594 $ 543 $ 591 $ 185 $ 102 $ 130 $ 57 $ 74 $ 94 Finance leases: PP&E 1,473 1,429 1,353 1,381 1,356 1,326 92 73 27 Accumulated depreciation (138) (99) (64) (107) (80) (57) (31) (19) (7) PP&E, net 1,335 1,330 1,289 1,274 1,276 1,269 61 54 20 Total ROU assets $ 1,929 $ 1,873 $ 1,880 $ 1,459 $ 1,378 $ 1,399 $ 118 $ 128 $ 114 Lease liabilities: Operating leases: Other current liabilities $ 49 $ 52 $ 52 $ 26 $ 27 $ 27 $ 15 $ 18 $ 18 Deferred credits and other 470 407 445 159 73 102 41 56 75 519 459 497 185 100 129 56 74 93 Finance leases: Current portion of long-term debt and finance leases 43 36 26 32 26 20 11 10 6 Long-term debt and finance leases 1,292 1,294 1,263 1,242 1,250 1,250 50 44 13 1,335 1,330 1,289 1,274 1,276 1,270 61 54 19 Total lease liabilities $ 1,854 $ 1,789 $ 1,786 $ 1,459 $ 1,376 $ 1,399 $ 117 $ 128 $ 112 Weighted-average remaining lease term (in years): Operating leases 14 13 13 11 6 6 4 5 6 Finance leases 17 18 19 17 19 20 7 7 6 Weighted-average discount rate: Operating leases 5.45 % 5.81 % 6.01 % 3.22 % 3.62 % 3.55 % 1.98 % 2.03 % 3.73 % Finance leases 14.25 % 14.45 % 14.76 % 14.48 % 14.65 % 14.83 % 2.91 % 2.83 % 3.23 %
Lease, Cost	The components of lease costs were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31, 2021 2020 2019 2021 2020 2019 2021 2020 2019 Operating lease costs $ 89 $ 92 $ 96 $ 32 $ 31 $ 33 $ 20 $ 24 $ 27 Finance lease costs: Amortization of ROU assets (2) 39 35 24 27 23 18 12 12 6 Interest on lease liabilities 186 188 173 184 186 173 2 2 — Total finance lease costs 225 223 197 211 209 191 14 14 6 Short-term lease costs (3) 7 7 6 1 3 2 — — — Variable lease costs (3) 432 477 482 422 467 471 10 10 10 Total lease costs $ 753 $ 799 $ 781 $ 666 $ 710 $ 697 $ 44 $ 48 $ 43 (1) Includes costs capitalized in PP&E. (2) Included in O&M, except for $22 at Sempra, $21 at SDG&E and $1 at SoCalGas in 2021, $18 at Sempra and SDG&E in 2020, and $15 at Sempra and SDG&E in 2019, which is included in Depreciation and Amortization Expense. (3) Short-term leases with variable lease costs are recorded and presented as variable lease costs.
Schedule of Cash Flow, Supplemental Disclosures	Cash paid for amounts included in the measurement of lease liabilities and supplemental noncash information were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31 2021 2020 2019 2021 2020 2019 2021 2020 2019 Operating activities: Cash paid for operating leases $ 78 $ 79 $ 101 $ 32 $ 31 $ 33 $ 20 $ 24 $ 27 Cash paid for finance leases 171 173 173 169 171 173 2 2 — Financing activities: Cash paid for finance leases 39 35 24 27 23 18 12 12 6 Increase (decrease) in operating lease obligations for ROU assets 116 20 585 112 (1) 158 1 1 118 Increase in finance lease obligations for investment in PP&E 43 77 38 24 30 16 19 47 22
Lessee, Operating Lease, Liability, Maturity	The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) December 31, 2021 Sempra SDG&E SoCalGas Operating leases (1) Finance leases (2) Operating leases (1) Finance leases (2) Operating leases Finance leases 2022 $ 73 $ 209 $ 30 $ 197 $ 17 $ 12 2023 66 208 27 197 13 11 2024 62 203 25 192 11 11 2025 50 199 16 188 10 11 2026 48 196 15 188 8 8 Thereafter 493 2,292 105 2,279 — 13 Total undiscounted lease payments 792 3,307 218 3,241 59 66 Less: imputed interest (273) (1,972) (33) (1,967) (3) (5) Total lease liabilities 519 1,335 185 1,274 56 61 Less: current lease liabilities (49) (43) (26) (32) (15) (11) Long-term lease liabilities $ 470 $ 1,292 $ 159 $ 1,242 $ 41 $ 50 (1) Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts. (2) Substantially all amounts are related to purchased-power contracts.
Finance Lease, Liability, Maturity	The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) December 31, 2021 Sempra SDG&E SoCalGas Operating leases (1) Finance leases (2) Operating leases (1) Finance leases (2) Operating leases Finance leases 2022 $ 73 $ 209 $ 30 $ 197 $ 17 $ 12 2023 66 208 27 197 13 11 2024 62 203 25 192 11 11 2025 50 199 16 188 10 11 2026 48 196 15 188 8 8 Thereafter 493 2,292 105 2,279 — 13 Total undiscounted lease payments 792 3,307 218 3,241 59 66 Less: imputed interest (273) (1,972) (33) (1,967) (3) (5) Total lease liabilities 519 1,335 185 1,274 56 61 Less: current lease liabilities (49) (43) (26) (32) (15) (11) Long-term lease liabilities $ 470 $ 1,292 $ 159 $ 1,242 $ 41 $ 50 (1) Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts. (2) Substantially all amounts are related to purchased-power contracts.
Lessor, Operating Lease, Payments to be Received, Maturity	LESSOR INFORMATION – SEMPRA (Dollars in millions) December 31, 2021 2020 2019 Assets subject to operating leases: Property, plant and equipment (1) $ 1,499 $ 1,092 $ 1,038 Accumulated depreciation (276) (228) (179) Property, plant and equipment, net $ 1,223 $ 864 $ 859 December 31, 2021 Maturity analysis of lease payments: Operating leases Sales-type leases 2022 $ 272 $ 16 2023 272 16 2024 273 17 2025 272 17 2026 272 9 Thereafter 3,031 — Total undiscounted cash flows $ 4,392 75 Present value of lease payments (recognized as lease receivable) (2) 55 Difference between undiscounted cash flows and discounted cash flows $ 20 (1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E. (2) Includes $9 in Other Current Assets and $46 in Other Long-Term Assets on the Consolidated Balance Sheet.
Operating Lease, Lease Income	LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA (Dollars in millions) Years ended December 31, 2021 2020 2019 Sales-type leases: Income recognized at lease commencement $ 18 $ 1 $ — Interest income 4 1 — Total revenues from sales-type leases (1) $ 22 $ 2 — Operating leases: Fixed lease payments $ 256 $ 195 $ 200 Variable lease payments 10 1 6 Total revenues from operating leases (1) $ 266 $ 196 $ 206 Depreciation expense $ 48 $ 39 $ 38 (1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.
Schedule Of Estimated Future Payments Under Natural Gas Contracts	At December 31, 2021, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts are as follows: FUTURE MINIMUM PAYMENTS (Dollars in millions) Sempra SoCalGas Storage and Natural gas (1) Total (1) Transportation 2022 $ 214 $ 20 $ 234 $ 134 2023 204 39 243 132 2024 181 15 196 114 2025 141 7 148 77 2026 137 — 137 75 Thereafter 903 — 903 310 Total minimum payments $ 1,780 $ 81 $ 1,861 $ 842 (1) Excludes amounts related to the LNG purchase agreement discussed below.
Schedule Of Payments Under Natural Gas Contracts	Total payments under natural gas contracts and natural gas storage and transportation contracts as well as payments to meet additional portfolio needs at Sempra and SoCalGas were as follows: PAYMENTS UNDER NATURAL GAS CONTRACTS (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra $ 1,691 $ 989 $ 1,326 SoCalGas 1,590 935 1,181
Schedule Of L N G Commitment Amounts	At December 31, 2021, the following LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted, under the agreement are delivered: LNG COMMITMENT AMOUNTS (Dollars in millions) Sempra: 2022 $ 435 2023 553 2024 516 2025 518 2026 519 Thereafter 1,381 Total $ 3,922
Schedule Of Estimated Future Payments Under Purchased Power Contracts	At December 31, 2021, the future minimum payments under long-term purchased-power contracts for Sempra and SDG&E are as follows: FUTURE MINIMUM PAYMENTS – PURCHASED-POWER CONTRACTS (Dollars in millions) 2022 $ 218 2023 188 2024 162 2025 105 2026 100 Thereafter 817 Total minimum payments (1) $ 1,590 (1) Excludes purchase agreements accounted for as operating leases and finance leases.
Schedule Of Environmental Remediation Costs Capitalized In Period	The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: CAPITAL EXPENDITURES FOR ENVIRONMENTAL ISSUES (Dollars in millions) Years ended December 31, 2021 2020 2019 Sempra $ 95 $ 76 $ 80 SDG&E 32 39 39 SoCalGas 63 37 41
Schedule Of Environmental Remediation Costs, Status Of Remediation Sites	The table below shows the status at December 31, 2021 of SDG&E’s and SoCalGas’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP: STATUS OF ENVIRONMENTAL SITES # Sites complete (1) # Sites SDG&E: Manufactured-gas sites 3 — Third-party waste-disposal sites 2 1 SoCalGas: Manufactured-gas sites 39 3 Third-party waste-disposal sites 5 2 (1) There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
Schedule of Environmental Loss Contingencies by Site	The following table shows our accrued liabilities for environmental matters at December 31, 2021. Of the total liability, $9 million at SoCalGas is recorded on a discounted basis, with a discount rate of 1.5%. ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS (Dollars in millions) Manufactured- Waste disposal sites (PRP) (1) Other Total (2) SDG&E (3) $ — $ 6 $ 12 $ 18 SoCalGas (4) 34 3 1 38 Other — 1 — 1 Total Sempra $ 34 $ 10 $ 13 $ 57 (1) Sites for which we have been identified as a PRP. (2) Includes $5, $2 and $3 classified as current liabilities, and $52, $16 and $35 classified as noncurrent liabilities on Sempra’s, SDG&E’s and SoCalGas’ Consolidated Balance Sheets, respectively. (3) Does not include SDG&E’s liability for SONGS marine environment mitigation. (4) Does not include SoCalGas’ liability for environmental matters for the Leak. We discuss matters related to the Leak above in “Legal Proceedings – SoCalGas – Aliso Canyon Natural Gas Storage Facility Gas Leak.”
Sales-type Lease, Lease Income	LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA (Dollars in millions) Years ended December 31, 2021 2020 2019 Sales-type leases: Income recognized at lease commencement $ 18 $ 1 $ — Interest income 4 1 — Total revenues from sales-type leases (1) $ 22 $ 2 — Operating leases: Fixed lease payments $ 256 $ 195 $ 200 Variable lease payments 10 1 6 Total revenues from operating leases (1) $ 266 $ 196 $ 206 Depreciation expense $ 48 $ 39 $ 38 (1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.
Sales-type and Direct Financing Leases, Lease Receivable, Maturity	LESSOR INFORMATION – SEMPRA (Dollars in millions) December 31, 2021 2020 2019 Assets subject to operating leases: Property, plant and equipment (1) $ 1,499 $ 1,092 $ 1,038 Accumulated depreciation (276) (228) (179) Property, plant and equipment, net $ 1,223 $ 864 $ 859 December 31, 2021 Maturity analysis of lease payments: Operating leases Sales-type leases 2022 $ 272 $ 16 2023 272 16 2024 273 17 2025 272 17 2026 272 9 Thereafter 3,031 — Total undiscounted cash flows $ 4,392 75 Present value of lease payments (recognized as lease receivable) (2) 55 Difference between undiscounted cash flows and discounted cash flows $ 20 (1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E. (2) Includes $9 in Other Current Assets and $46 in Other Long-Term Assets on the Consolidated Balance Sheet.

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables show selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 6. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2021 2020 2019 REVENUES SDG&E $ 5,504 $ 5,313 $ 4,925 SoCalGas 5,515 4,748 4,525 Sempra Infrastructure 1,997 1,400 1,454 Sempra Renewables — — 10 All other 5 2 3 Adjustments and eliminations (1) (3) (3) Intersegment revenues (1) (163) (90) (85) Total $ 12,857 $ 11,370 $ 10,829 DEPRECIATION AND AMORTIZATION SDG&E $ 889 $ 801 $ 760 SoCalGas 716 654 602 Sempra Infrastructure 239 198 193 All other 11 13 14 Total $ 1,855 $ 1,666 $ 1,569 INTEREST INCOME SDG&E $ 1 $ 2 $ 4 SoCalGas 1 2 2 Sempra Infrastructure 75 141 139 Sempra Renewables — — 11 All other 3 7 4 Intercompany eliminations (11) (56) (73) Total $ 69 $ 96 $ 87 INTEREST EXPENSE SDG&E $ 412 $ 413 $ 411 SoCalGas 157 158 141 Sempra Infrastructure 205 174 155 Sempra Renewables — — 3 All other 444 390 450 Intercompany eliminations (20) (54) (83) Total $ 1,198 $ 1,081 $ 1,077 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 201 $ 190 $ 171 SoCalGas (310) 96 120 Sempra Texas Utilities — 1 — Sempra Infrastructure 238 149 222 Sempra Renewables — — 4 All other (30) (187) (202) Total $ 99 $ 249 $ 315 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 819 $ 824 $ 767 SoCalGas (427) 504 641 Sempra Texas Utilities 616 579 528 Sempra Infrastructure 682 580 247 Sempra Renewables — — 59 Discontinued operations — 1,840 328 All other (436) (563) (515) Total $ 1,254 $ 3,764 $ 2,055 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2021 2020 2019 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 2,220 $ 1,942 $ 1,522 SoCalGas 1,984 1,843 1,439 Sempra Infrastructure 802 879 736 Sempra Renewables — — 2 All other 9 12 9 Total $ 5,015 $ 4,676 $ 3,708 ASSETS SDG&E $ 24,058 $ 22,311 $ 20,560 SoCalGas 20,324 18,460 17,077 Sempra Texas Utilities 13,047 12,542 11,619 Sempra Infrastructure 14,408 12,772 13,660 Discontinued operations — — 3,958 All other 1,399 1,215 763 Intersegment receivables (1,191) (677) (1,972) Total $ 72,045 $ 66,623 $ 65,665 GEOGRAPHIC INFORMATION Long-lived assets (2) : United States $ 50,657 $ 46,902 $ 43,719 Mexico $ 7,708 $ 6,929 $ 6,355 Asia 1 — — Total $ 58,366 $ 53,831 $ 50,074 Revenues (3) : United States $ 11,154 $ 10,205 $ 9,574 Mexico 1,703 1,165 1,255 Total $ 12,857 $ 11,370 $ 10,829 (1) Revenues for reportable segments include intersegment revenues of $10, $98, and $55 for 2021; $5, $88, and $(3) for 2020; and $5, $69, and $11 for 2019 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively. (2) Includes net PP&E and investments. (3) Amounts are based on where the revenue originated, after intercompany eliminations.

SCHEDULE I - CONDENSED FINANC_2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
Schedule of Condensed Statements of Operations	SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2021 2020 2019 Interest income $ 11 $ 4 $ 3 Interest expense (576) (495) (521) Operating expenses (92) (86) (124) Other income (expense), net 20 (38) 59 Income tax benefit 190 176 163 Loss before equity in earnings of subsidiaries (447) (439) (420) Equity in earnings of subsidiaries, net of income taxes 1,764 4,371 2,617 Net income 1,317 3,932 2,197 Preferred dividends (63) (168) (142) Earnings $ 1,254 $ 3,764 $ 2,055 Basic EPS: Earnings $ 4.03 $ 12.93 $ 7.40 Weighted-average common shares outstanding 311,755 291,077 277,904 Diluted EPS: Earnings $ 4.01 $ 12.88 $ 7.29 Weighted-average common shares outstanding 313,036 292,252 282,033 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Statements Of Comprehensive Income	SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2021, 2020 and 2019 Pretax Income tax benefit (expense) Net-of-tax 2021: Net income $ 1,127 $ 190 $ 1,317 Other comprehensive income (loss): Foreign currency translation adjustments (6) — (6) Financial instruments 191 (47) 144 Pension and other postretirement benefits 28 (6) 22 Total other comprehensive income 213 (53) 160 Comprehensive income $ 1,340 $ 137 $ 1,477 2020: Net income $ 3,756 $ 176 $ 3,932 Other comprehensive income (loss): Foreign currency translation adjustments 547 — 547 Financial instruments (146) 33 (113) Pension and other postretirement benefits 11 1 12 Total other comprehensive income 412 34 446 Comprehensive income $ 4,168 $ 210 $ 4,378 2019: Net income $ 2,034 $ 163 $ 2,197 Other comprehensive income (loss): Foreign currency translation adjustments (43) — (43) Financial instruments (161) 53 (108) Pension and other postretirement benefits 25 (7) 18 Total other comprehensive loss (179) 46 (133) Comprehensive income $ 1,855 $ 209 $ 2,064 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Balance Sheets	SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, 2021 2020 2019 Assets: Cash and cash equivalents $ 186 $ 366 $ 6 Restricted cash 2 — — Due from affiliates 446 58 98 Income taxes receivable, net — 42 — Other current assets 31 26 34 Total current assets 665 492 138 Investments in subsidiaries 33,308 33,898 32,604 Due from affiliates 21 1 3 Deferred income taxes 626 2,187 1,766 Other long-term assets 1,090 717 682 Total assets $ 35,710 $ 37,295 $ 35,193 Liabilities and shareholders’ equity: Short-term debt $ 1,240 $ — $ — Current portion of long-term debt — 850 1,399 Due to affiliates 185 224 369 Income taxes payable, net 4 — 274 Other current liabilities 531 536 561 Total current liabilities 1,960 1,610 2,603 Long-term debt 5,969 7,317 8,856 Due to affiliates 1,151 4,375 3,138 Other long-term liabilities 649 620 667 Commitments and contingencies (Note 4) Shareholders’ equity 25,981 23,373 19,929 Total liabilities and shareholders’ equity $ 35,710 $ 37,295 $ 35,193 See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Statements of Cash Flows	SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2021 2020 2019 Net cash (used in) provided by operating activities $ (255) $ (978) $ 294 Expenditures for property, plant and equipment (8) (9) (8) Capital contributions to investees (1,005) (364) (1,528) Disbursement for note receivable (305) — — Distribution from investments 1,552 3,616 — (Increase) decrease in loans to affiliates, net (20) 2 — Other — — 4 Net cash provided by (used in) investing activities 214 3,245 (1,532) Common stock dividends paid (1,331) (1,174) (993) Preferred dividends paid (99) (157) (142) Issuances of preferred stock, net — 891 — Issuances of common stock, net 5 11 1,830 Repurchases of common stock (339) (566) (26) Issuances of long-term debt 990 1,599 758 Payments on long-term debt (3,200) (3,700) (1,500) Increase in short-term debt 1,240 — — Increase in loans from affiliates, net 1,092 1,194 1,328 Purchases of noncontrolling interest (217) — — Proceeds from sale of noncontrolling interest 1,846 — — Equity transaction costs with third parties — (4) — Debt issuance costs — (1) (25) Make-whole premiums related to early redemptions of debt (121) — — Other financing (2) — — Net cash (used in) provided by financing activities (136) (1,907) 1,230 Effect of exchange rate changes on cash and cash equivalents (1) — — (Decrease) increase in cash and cash equivalents (178) 360 (8) Cash and cash equivalents, January 1 366 6 14 Cash, cash equivalents and restricted cash, December 31 $ 188 $ 366 $ 6 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Issuance of common stock in exchange for NCI and related AOCI $ 1,373 $ — $ — Common dividends issued in stock — 22 55 Common dividends declared but not paid 349 301 283 Conversion of mandatory convertible preferred stock 2,258 — — Preferred dividends declared but not paid 11 47 36 Equitization of amounts due from affiliates 4,351 — —
Schedule Of Long-term Debt	The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2021 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ — $ 350 $ 350 1.914% payable 2015 through February 2022 17 53 89 3.6% September 1, 2023 450 450 450 2.5% May 15, 2026 500 500 500 6% June 1, 2026 250 250 250 1.7% October 1, 2030 800 800 — 5.875% January and February 2034 (1) — — 176 5.35% May 15, 2035 250 250 250 6.125% September 15, 2037 250 250 250 4% May 1, 2039 (1) — — 75 6% June 1, 2039 300 300 300 5.35% May 15, 2040 250 250 250 4.5% August 15, 2040 500 500 500 3.95% November 15, 2041 250 250 250 4.3% April 1, 2042 250 250 250 3.75% June 1, 2047 400 400 400 4.15% May 15, 2048 400 400 400 4.1% June 15, 2049 400 400 400 3.32% April 15, 2050 400 400 — 2.95% August 15, 2051 750 — — 6,417 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) — 200 — Finance lease obligations: Purchased-power contracts 1,217 1,237 1,255 Other 57 39 15 1,274 1,476 1,270 7,691 7,529 6,410 Current portion of long-term debt (49) (611) (56) Unamortized discount on long-term debt (17) (13) (12) Unamortized debt issuance costs (44) (39) (36) Total SDG&E 7,581 6,866 6,306 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ 500 $ 500 $ 500 3.2% June 15, 2025 350 350 350 2.6% June 15, 2026 500 500 500 2.55% February 1, 2030 650 650 — 5.75% November 15, 2035 250 250 250 5.125% November 15, 2040 300 300 300 3.75% September 15, 2042 350 350 350 4.45% March 15, 2044 250 250 250 4.125% June 1, 2048 400 400 400 4.3% January 15, 2049 550 550 550 3.95% February 15, 2050 350 350 350 4,450 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.55% at December 31, 2021) September 14, 2023 (1) 300 300 — 1.875% Notes May 14, 2026 (1) 4 4 4 5.67% Notes January 18, 2028 (2) 5 5 5 Finance lease obligations 61 54 19 370 363 28 4,820 4,813 3,828 Current portion of long-term debt (11) (10) (6) Unamortized discount on long-term debt (7) (8) (7) Unamortized debt issuance costs (29) (32) (27) Total SoCalGas 4,773 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2021 2020 2019 Sempra: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 Sempra Infrastructure: Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 189 197 207 Loan at variable rates (2.93% at December 31, 2021) December 9, 2025 341 17 — Notes at 2.87% to 3.51% October 1, 2026 (1) — — 22 Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets (2) 154 196 237 3.75% Notes January 14, 2028 300 300 300 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — — 11 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets — 398 423 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 200 2.9% Loan November 15, 2034 (1) 241 241 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 100 — 4.875% Notes January 14, 2048 540 540 540 4.75% Notes January 15, 2051 800 800 — 8,923 11,247 12,298 Current portion of long-term debt (46) (919) (1,464) Unamortized discount on long-term debt (65) (55) (35) Unamortized debt issuance costs (98) (121) (108) Total other Sempra 8,714 10,152 10,691 Total Sempra $ 21,068 $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2021 2020 2019 2.4% Notes February 1, 2020 $ — $ — $ 500 2.4% Notes March 15, 2020 — — 500 2.85% Notes November 15, 2020 — — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — — 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 — 850 850 2.875% Notes October 1, 2022 — 500 500 2.9% Notes February 1, 2023 — 500 500 4.05% Notes December 1, 2023 — 500 500 3.55% Notes June 15, 2024 — 500 500 3.75% Notes November 15, 2025 — 350 350 3.25% Notes June 15, 2027 750 750 750 3.4% Notes February 1, 2028 1,000 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 1,000 6% Notes October 15, 2039 750 750 750 4% Notes February 1, 2048 800 800 800 4.125% Junior Subordinated Notes April 1, 2052 (1) 1,000 — — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 758 6,058 8,258 10,358 Current portion of long-term debt — (850) (1,399) Unamortized discount on long-term debt (37) (32) (35) Unamortized debt issuance costs (52) (59) (68) Total long-term debt $ 5,969 $ 7,317 $ 8,856 (1) Callable long-term debt not subject to make-whole provisions.

SIGNIFICANT ACCOUNTING POLICI_4

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	21 Months Ended
	Dec. 31, 2020segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

SIGNIFICANT ACCOUNTING POLICI_5

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - REGULATED OPERATIONS (Details)	Dec. 31, 2021
Oncor Electric Delivery Company LLC | Oncor Holdings | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	80.25%
Sharyland Utilities, LP | Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%

SIGNIFICANT ACCOUNTING POLICI_6

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Presentation Of Restricted Cash [Line Items]
Cash and cash equivalents	$ 559	$ 960	$ 108
Restricted cash, current	19	22	31
Restricted cash, noncurrent	3	3	3
Cash, cash equivalents and restricted cash in discontinued operations	0	0	75
Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows	$ 581	985	217	$ 246
Discontinued Operations, Held-for-sale | Sempra South American Utilities
Presentation Of Restricted Cash [Line Items]
Cash, cash equivalents and restricted cash in discontinued operations			1
Cash and cash equivalents		$ 4,600	$ 74

SIGNIFICANT ACCOUNTING POLICI_7

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	$ 138	$ 29	$ 21
Provisions for expected credit losses	45	124	22
Write-offs	(47)	(16)	(14)
Allowances for credit losses at December 31	136	138	29
KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Note receivable issued	300
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	94	111	7
Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	39	27	22
Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	3	0	0
Other long-term assets | KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	8
Due from Unconsolidated Affiliates - Noncurrent
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Financing receivable, allowance for credit loss	1	3
Deferred Credits and Other | Sempra Infrastructure
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit loss related to guarantees	7
Cumulative Effect, Period of Adoption, Adjustment
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	0	1	0
Allowances for credit losses at December 31		0	1
San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	69	14	11
Provisions for expected credit losses	23	65	10
Write-offs	(26)	(10)	(7)
Allowances for credit losses at December 31	66	69	14
San Diego Gas and Electric Company [Member] | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	42	55	4
San Diego Gas and Electric Company [Member] | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	22	14	10
San Diego Gas and Electric Company [Member] | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	2	0	0
SoCalGas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	68	15	10
Provisions for expected credit losses	22	59	12
Write-offs	(21)	(6)	(7)
Allowances for credit losses at December 31	69	68	15
SoCalGas | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	51	55	3
SoCalGas | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	17	13	12
SoCalGas | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	$ 1	$ 0	$ 0

SIGNIFICANT ACCOUNTING POLICI_8

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Inventory [Line Items]
Natural Gas	$ 164	$ 118	$ 110
LNG	27	7	9
Materials And Supplies	198	183	158
Inventories	389	308	277
San Diego Gas and Electric Company [Member]
Inventory [Line Items]
Natural Gas	0	0	1
LNG	0	0	0
Materials And Supplies	123	104	93
Inventories	123	104	94
SoCalGas
Inventory [Line Items]
Natural Gas	114	94	90
LNG	0	0	0
Materials And Supplies	58	59	46
Inventories	$ 172	$ 153	$ 136

SIGNIFICANT ACCOUNITNG POLICIES

SIGNIFICANT ACCOUNITNG POLICIES AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Receivables with Imputed Interest [Line Items]
Note receivable issued	$ 300
Transaction costs	$ 5
Note receivable interest rate (as a percent)	5.00%
Other long-term assets
Receivables with Imputed Interest [Line Items]
Note receivable, net	$ 297
Other current assets
Receivables with Imputed Interest [Line Items]
Note receivable, net	$ 3

SIGNIFICANT ACCOUNTING POLICI_9

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($)	1 Months Ended	12 Months Ended
	Jul. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Loss Contingencies [Line Items]
Noncurrent portion of the Wildfire Fund asset		$ 331,000,000	$ 363,000,000	$ 392,000,000
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Fire risk mitigation capital improvements	$ 215,000,000
Initial liability cap		1,100,000,000
Initial shareholder contributions					$ 322,500,000
Additional annual contributions, aggregate value		129,000,000
Wildfire fund asset				451,500,000
Annual contributions		$ 12,900,000
Amortization of wildfire fund asset		15 years
Current portion of Wildfire fund		$ 29,000,000	29,000,000	29,000,000
Noncurrent portion of the Wildfire Fund asset		331,000,000	363,000,000	392,000,000
Wildfire fund obligations in current liabilities		13,000,000	13,000,000	13,000,000
Noncurrent Wildfire Fund obligation		64,000,000	75,000,000	86,000,000
Amortization of Wildfire Fund asset		29,000,000	29,000,000	12,000,000
Wildfire Fund asset, impairment losses		3,000,000	0	0
Accretion of Wildfire Fund obligation		2,000,000	$ 2,000,000	$ 1,000,000
Wildfire Fund
Loss Contingencies [Line Items]
Wildfire fund, threshold amount to seek payment	$ 1,000,000,000
Wildfire fund, threshold percentage of equity portion of electric transmission	20.00%
Liquidity fund, maximum borrowing capacity		10,500,000,000
Initial shareholder contributions		7,500,000,000
Additional annual contributions, aggregate value		$ 3,000,000,000
Period of annual contributions		10 years

SIGNIFICANT ACCOUNTING POLIC_10

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 58,940	$ 53,928	$ 49,329
Depreciation expense	1,833	1,646	1,551
Accumulated depreciation	15,046	13,925	12,877
San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	26,456	24,436	22,504
Depreciation expense	884	797	757
Accumulated depreciation	6,408	6,015	5,537
SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	23,104	21,180	19,362
Depreciation expense	711	649	598
Accumulated depreciation	6,861	6,437	6,038
Natural gas operations | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,200	$ 2,805	$ 2,534
Depreciation rates (percentage)	2.55%	2.51%	2.47%
Accumulated depreciation	$ 919	$ 870	$ 832
Natural gas operations | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 21,894	$ 19,961	$ 18,370
Depreciation rates (percentage)	3.65%	3.63%	3.60%
Accumulated depreciation	$ 6,845	$ 6,422	$ 6,023
Electric distribution | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 9,471	$ 8,592	$ 7,985
Depreciation rates (percentage)	3.93%	3.90%	3.94%
Electric transmission | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 7,577	$ 7,156	$ 6,577
Depreciation rates (percentage)	3.02%	3.10%	2.79%
Electric generation | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,446	$ 2,440	$ 2,415
Depreciation rates (percentage)	4.74%	4.56%	4.50%
Other electric | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,100	$ 1,743	$ 1,492
Depreciation rates (percentage)	7.23%	6.92%	6.61%
Other non-utility | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 50	$ 45	$ 34
Depreciation rates (percentage)	2.23%	3.80%	5.08%
Accumulated depreciation	$ 16	$ 15	$ 15
Other non-utility | Sempra Infrastructure and parent
Property, Plant and Equipment [Line Items]
Accumulated depreciation	1,777	1,473	1,302
Land and land rights | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 291	283	278
Land and land rights | Minimum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	16 years
Land and land rights | Maximum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Land and land rights | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	36 years
Pipelines and storage | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,698	3,482	3,596
Pipelines and storage | Minimum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	5 years
Pipelines and storage | Maximum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Pipelines and storage | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	42 years
Generating plants | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,659	1,288	1,154
Generating plants | Minimum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	11 years
Generating plants | Maximum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	30 years
Generating plants | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	27 years
LNG terminals | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,138	1,138	1,134
Estimated useful life	43 years
LNG terminals | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	43 years
Liquid fuels terminals | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 420	0	0
Estimated useful life	37 years
Liquid fuels terminals | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	37 years
Other | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 370	359	180
Other | Minimum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	3 years
Other | Maximum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Other | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	13 years
Construction work in progress | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,662	1,700	1,501
Construction work in progress | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,160	1,174	958
Construction work in progress | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,494	1,514	895
Other | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 310	248	226
Other | Minimum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	4 years
Other | Maximum | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Other | Weighted Average | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Estimated useful life	21 years
Total Other Operating Units And Parent | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 9,380	8,312	7,463
Plant, pipeline and other distribution assets of ecogas
Property, Plant and Equipment [Line Items]
Accumulated depreciation	55	51	49
Plant, pipeline and other distribution assets of ecogas | Other Operating Units and Parent
Property, Plant and Equipment [Line Items]
Property, plant and equipment	211	191	178
Electric | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	5,489	$ 5,145	$ 4,705
Southwest Powerlink (SWPL) transmission line | Electric transmission | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	542
Accumulated depreciation	292
Southwest Powerlink (SWPL) transmission line | Construction work in progress | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 5
Southwest Powerlink | Southwest Powerlink (SWPL) transmission line | Electric transmission | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Ownership interest (as a percent)	86.00%

SIGNIFICANT ACCOUNTING POLIC_11

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 217	$ 202	$ 183
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	106	104	75
SoCalGas
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 64	$ 55	$ 47

SIGNIFICANT ACCOUNTING POLIC_12

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,602	$ 1,602	$ 1,602
Total intangible assets, gross	440	250	250
Accumulated amortization	(70)	(48)	(37)
Other intangible assets	370	202	213
Intangible assets amortization expense	22	11	11
Amortization recorded against revenues	10
Expected amortization, year one	26
Expected amortization, year two	26
Expected amortization, year three	26
Expected amortization, year four	26
Expected amortization, year five	26
Expected amortization expense recorded against revenue, next five years	13
Renewable energy transmission and consumption permits
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	169	169	169
Accumulated amortization	$ (40)	(32)	(24)
Renewable energy transmission and consumption permits | Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	15 years
Renewable energy transmission and consumption permits | Maximum
Finite-Lived Intangible Assets [Line Items]
Amortization period	19 years
O&M agreement
Finite-Lived Intangible Assets [Line Items]
Amortization period	23 years
Intangible assets, gross	$ 66	66	66
Accumulated amortization	$ (12)	(9)	(6)
ESJ PPA
Finite-Lived Intangible Assets [Line Items]
Amortization period	14 years
Intangible assets, gross	$ 190	0	0
Accumulated amortization	(10)	0	0
Other
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	15	15	15
Accumulated amortization	$ (8)	$ (7)	$ (7)
Other | Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	10 years

SIGNIFICANT ACCOUNTING POLIC_13

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details)	9 Months Ended	12 Months Ended
	Oct. 03, 2019MW	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Variable Interest Entity [Line Items]
Total finance leases		$ 1,335,000,000	$ 1,330,000,000	$ 1,289,000,000
Property, plant and equipment, net		43,894,000,000	40,003,000,000	36,452,000,000
Equity method investment		12,947,000,000	12,440,000,000	11,519,000,000
Assets		72,045,000,000	66,623,000,000	65,665,000,000
San Diego Gas and Electric Company [Member]
Variable Interest Entity [Line Items]
Total finance leases		1,274,000,000	1,276,000,000	1,270,000,000
Property, plant and equipment, net		20,048,000,000	18,421,000,000	16,967,000,000
Assets		24,058,000,000	22,311,000,000	20,560,000,000
San Diego Gas and Electric Company [Member] | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Total finance leases		1,217,000,000	1,237,000,000	1,255,000,000
Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Debt instrument, maximum borrowing amount		979,000,000
Sempra Infrastructure | Cameron LNG JV
Variable Interest Entity [Line Items]
Equity method investment		514,000,000	433,000,000	1,256,000,000
Sempra Infrastructure | ECA LNG JV | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Assets		632,000,000	207,000,000
Liabilities		$ 455,000,000	49,000,000
Oncor Electric Delivery Company LLC | Oncor Holdings
Variable Interest Entity [Line Items]
Ownership percentage held by noncontrolling owners		80.25%
Oncor Holdings | Sempra Texas Utilities
Variable Interest Entity [Line Items]
Equity method investment		$ 12,947,000,000	$ 12,440,000,000	$ 11,519,000,000
Sempra Texas Holdings Corp | Oncor Holdings | Sempra Texas Utilities
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity		100.00%
Otay Mesa VIE | San Diego Gas and Electric Company [Member] | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Generating capacity (in mw) | MW	605

SIGNIFICANT ACCOUNTING POLIC_14

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 3,289	$ 3,083	$ 2,972
Accretion expense	133	127	123
Liabilities incurred and acquired	20	2	2
Deconsolidation	0	0	(2)
Payments	(63)	(63)	(46)
Revisions	159	140	34
Ending Balance	3,538	3,289	3,083
San Diego Gas and Electric Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	876	866	874
Accretion expense	38	39	39
Liabilities incurred and acquired	2	0	0
Deconsolidation	0	0	(2)
Payments	(60)	(60)	(44)
Revisions	34	31	(1)
Ending Balance	890	876	866
Revisions for early decommissioning of SONGS	22
SoCalGas
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2,368	2,177	2,063
Accretion expense	92	86	81
Liabilities incurred and acquired	0	0	0
Deconsolidation	0	0	0
Payments	(3)	(2)	(2)
Revisions	125	107	35
Ending Balance	$ 2,582	$ 2,368	$ 2,177

SIGNIFICANT ACCOUNTING POLIC_15

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	$ 23,373	$ 19,929
AOCI, ending balance	25,981	23,373	$ 19,929
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	7,730	7,100
AOCI, ending balance	8,249	7,730	7,100
SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	5,144	4,748
AOCI, ending balance	5,442	5,144	4,748
Foreign currency translation adjustments
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(64)	(607)	(564)
OCI before reclassifications(3)	(34)	(102)	(43)
Amounts reclassified from AOCI(3)	19	645	0
Total other comprehensive income (loss)	(15)	543	(43)
AOCI, ending balance	(79)	(64)	(607)
AOCI associated with noncontrolling interests	19
Foreign currency translation adjustments | IEnova
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	28	4
Foreign currency translation adjustments | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			0
Financial instruments
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(331)	(215)	(82)
OCI before reclassifications(3)	62	(163)	(116)
Amounts reclassified from AOCI(3)	113	47	8
Total other comprehensive income (loss)	175	(116)	(108)
AOCI, ending balance	(156)	(331)	(215)
AOCI associated with noncontrolling interests	47
Financial instruments | IEnova
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	16	3
Financial instruments | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(25)
Financial instruments | SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(13)	(13)	(12)
OCI before reclassifications(3)	0	0	0
Amounts reclassified from AOCI(3)	0	0	1
Total other comprehensive income (loss)	0	0	1
AOCI, ending balance	(13)	(13)	(13)
Financial instruments | SoCalGas | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Pension and other postretirement benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(105)	(117)	(118)
OCI before reclassifications(3)	8	(26)	(18)
Amounts reclassified from AOCI(3)	14	38	36
Total other comprehensive income (loss)	22	12	18
AOCI, ending balance	(83)	(105)	(117)
Pension and other postretirement benefits | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI(3)		3
Pension and other postretirement benefits | SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI(3)			4
Pension and other postretirement benefits | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(17)
Pension and other postretirement benefits | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(10)	(16)	(10)
OCI before reclassifications(3)	(1)	(4)	(5)
Amounts reclassified from AOCI(3)	1	10	1
Total other comprehensive income (loss)	0	6	(4)
AOCI, ending balance	(10)	(10)	(16)
Pension and other postretirement benefits | San Diego Gas and Electric Company [Member] | SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI(3)		6
Pension and other postretirement benefits | San Diego Gas and Electric Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Pension and other postretirement benefits | SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(18)	(10)	(8)
OCI before reclassifications(3)	(2)	(10)	(4)
Amounts reclassified from AOCI(3)	2	2	4
Total other comprehensive income (loss)	0	(8)	0
AOCI, ending balance	(18)	(18)	(10)
Pension and other postretirement benefits | SoCalGas | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Accumulated other comprehensive income (loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(500)	(939)	(764)
OCI before reclassifications(3)	36	(291)	(177)
Amounts reclassified from AOCI(3)	146	730	44
Total other comprehensive income (loss)	182	439	(133)
AOCI, ending balance	(318)	(500)	(939)
Accumulated other comprehensive income (loss) | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(42)
Accumulated other comprehensive income (loss) | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(10)	(16)	(10)
OCI before reclassifications(3)	(1)	(4)	(5)
Amounts reclassified from AOCI(3)	1	10	1
Total other comprehensive income (loss)	0	6	(4)
AOCI, ending balance	(10)	(10)	(16)
Accumulated other comprehensive income (loss) | San Diego Gas and Electric Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Accumulated other comprehensive income (loss) | SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(31)	(23)	(20)
OCI before reclassifications(3)	(2)	(10)	(4)
Amounts reclassified from AOCI(3)	2	2	5
Total other comprehensive income (loss)	0	(8)	1
AOCI, ending balance	$ (31)	$ (31)	(23)
Accumulated other comprehensive income (loss) | SoCalGas | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			$ (4)

SIGNIFICANT ACCOUNTING POLIC_16

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	$ 0	$ 1,840	$ 328
Gain (loss) on sale of assets	36	(3)	63
Interest expense	(1,198)	(1,081)	(1,077)
Equity earnings	1,343	1,015	580
Energy-related businesses	1,866	1,345	1,381
Other (expense) income, net	(58)	48	(77)
Income from continuing operations before income taxes and equity earnings	219	1,489	1,734
Income tax benefit (expense)	(99)	(249)	(315)
Income from continuing operations, net of income tax	1,463	2,255	1,999
Earnings attributable to noncontrolling interest	(145)	(172)	(164)
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(412)	(413)	(411)
Other (expense) income, net	(64)	(52)	(39)
Income from continuing operations before income taxes and equity earnings	1,020	1,014	945
Income tax benefit (expense)	(201)	(190)	(171)
Earnings attributable to noncontrolling interest	0	0	(7)
SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(157)	(158)	(141)
Other (expense) income, net	14	28	55
Income from continuing operations before income taxes and equity earnings	(736)	601	762
Income tax benefit (expense)	310	(96)	(120)
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	80	721	40
Reclassification out of Accumulated Other Comprehensive Income | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	2	2	1
Reclassification out of Accumulated Other Comprehensive Income | Foreign currency translation adjustments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	645	0
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings	92	67	11
Income tax benefit (expense)	(24)	(19)	(2)
Income from continuing operations, net of income tax	68	48	9
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments | Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain (loss) on sale of assets	0	0	10
Interest expense	11	10	3
Equity earnings	73	46	3
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments | Interest rate instruments | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	0	0	3
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments | Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	0	0	2
Energy-related businesses	1	(1)	2
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments | Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	1	0
Other (expense) income, net	6	11	(9)
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments attributable to Noncontrolling interests
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest	(2)	(1)	(1)
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments attributable to Noncontrolling interests | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest	0	0	(3)
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments attributable to parent
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	66	47	8
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments attributable to parent | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	0	0	0
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments attributable to parent | Interest rate instruments | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	0	0	1
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	6	1
Other (expense) income, net	8	8	12
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	0	1	0
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	4	4	3
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	1	1	0
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	7	22	28
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	(2)	0
Income from continuing operations before income taxes and equity earnings	19	40	44
Income tax benefit (expense)	(5)	(9)	(12)
Income from continuing operations, net of income tax	14	29	32
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings	1	2	1
Income tax benefit (expense)	0	(1)	0
Income from continuing operations, net of income tax	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings	2	2	1
Income tax benefit (expense)	0	0	(1)
Income from continuing operations, net of income tax	$ 2	$ 2	$ 0

SIGNIFICANT ACCOUNTING POLIC_17

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Oct. 01, 2021	Dec. 31, 2020	Dec. 31, 2019
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 1,418		$ 1,541	$ 1,856
SI Partners | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	20.00%	0.20%
Other noncontrolling interests	$ 1,384		0	0
SI Partners Subsidiaries | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 34		$ 1,540	$ 1,622
SI Partners Subsidiaries | Sempra Infrastructure | Minimum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.10%		17.50%	10.00%
SI Partners Subsidiaries | Sempra Infrastructure | Maximum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	16.60%		29.80%	46.30%
PXISE Energy Solutions LLC | Corporate and Other
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners			20.00%	20.00%
Other noncontrolling interests	$ 0		$ 1	$ 1
Chilquinta Energia subsidiaries | Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Other noncontrolling interests	0		0	$ 23
Chilquinta Energia subsidiaries | Discontinued Operations, Held-for-sale | Minimum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners				19.70%
Chilquinta Energia subsidiaries | Discontinued Operations, Held-for-sale | Maximum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners				43.40%
Luz del Sur | Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners				16.40%
Other noncontrolling interests	0		0	$ 205
Tecsur | Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners				9.80%
Other noncontrolling interests	$ 0		$ 0	$ 5

SIGNIFICANT ACCOUNTING POLIC_18

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details) $ / shares in Units, $ / shares in Units, $ in Millions, $ in Billions	Oct. 01, 2021USD ($)	Mar. 30, 2020USD ($)	Feb. 07, 2019	Oct. 31, 2021USD ($)	Sep. 30, 2021USD ($)$ / sharesshares	Sep. 30, 2021MXN ($)$ / sharesshares	Jul. 31, 2021USD ($)	May 31, 2021USD ($)shares	Dec. 31, 2020	Feb. 28, 2019USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2021USD ($)shares	Dec. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)shares	Feb. 16, 2022shares	Dec. 21, 2021USD ($)	Oct. 15, 2021$ / shares	Apr. 30, 2021	Dec. 31, 2018
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest												$ 2,712	$ 28	$ 5
Stock repurchased in the period												339	566	26
Income tax expense (benefit)												99	249	315
Equitization of long-term debt for deficit held by NCI													(22)
Noncontrolling Interest, Decrease from Deconsolidation												(1)	236	440
Proceeds from sales of noncontrolling interests, net												$ 3,206	$ 26	$ 5
Shares issued in IEnova exchange offer | shares								12,306,777				12,306,777	0	0
IEnova
Noncontrolling Interest [Line Items]
Common stock exchange ratio								0.0323
Increase in shareholders' equity					$ 72
Common Stock, Shares, Acquired | shares					51,014,545	51,014,545		381,015,194
Common stock acquired					$ 202	$ 4
Share price (in dollars per share) | (per share)					$ 3.95	$ 78.97
Sempra Infrastructure | IEnova
Noncontrolling Interest [Line Items]
Stock repurchased in the period											$ 9		$ 231	$ 10
Stock repurchased during the period (in shares) | shares													77,122,780	2,620,000
IEnova
Noncontrolling Interest [Line Items]
Noncontrolling interest, percent of funding	20.00%
IEnova | SI Partners
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners												99.90%
IEnova | Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage sold									16.60%
IEnova | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)									70.20%				70.20%	66.60%					66.50%
Bay Gas | Sempra LNG
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)			9.10%
Cash consideration (fair value of total consideration)										$ 20
ICM Ventures Holdings B.V. [Member] | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners							17.50%
Ownership interest (as a percent)											82.50%			53.70%
Payments to acquire minority interest							$ 7
Liberty Gas Storage [Member] | Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		24.60%
IEnova
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	99.90%				99.90%	99.90%		96.40%										70.20%
Increase in shareholders' equity					$ 17			$ 1,400
Share price (in pesos per share) | $ / shares																	$ 78.97
Noncontrolling Interest, Decrease from Deconsolidation					188			1,400
Purchase of noncontrolling interest, transaction costs					$ 4			$ 12
Noncontrolling interest, remaining shares of noncontrolling interest | shares												1,212,981
IEnova | Subsequent Event
Noncontrolling Interest [Line Items]
Noncontrolling interest, remaining shares of noncontrolling interest | shares															629,784
IEnova | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)												99.90%
SI Partners
Noncontrolling Interest [Line Items]
Ownership interest in partnership (as a percent)	80.00%
Distribution requirement (as a percent)	85.00%
SI Partners | Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest, purchase price																$ 1,800
Sale of noncontrolling interest (as a percent)																10.00%
SI Partners | KKR
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest (as a percent)				20.00%
Income tax expense (benefit)				$ 72
SI Partners | Sempra Energy
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners																70.00%
SI Partners | KKR
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners																20.00%
SI Partners | Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners																10.00%
SI Partners | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.20%											20.00%
Sale of noncontrolling interest, purchase price	$ 3,400
Increase in the noncontrolling interest balance from the sale of noncontrolling interest	1,300
Sale of noncontrolling interest, change in equity	1,400
Sale of noncontrolling interest, transaction costs	173
Sale of noncontrolling interest, deferred income tax liability	490
Sale of noncontrolling interest, transaction costs reimbursed	$ 149
Ownership interest (as a percent)												80.00%
Bay Gas | Sempra LNG
Noncontrolling Interest [Line Items]
Sale of interest (as a percent)			100.00%
Liberty Gas Storage, LLC | Sempra LNG
Noncontrolling Interest [Line Items]
Payments to acquire minority interest		$ 7
Equitization of long-term debt for deficit held by NCI		22
Increase from equity of noncontrolling interest		$ 2
Liberty Gas Storage, LLC | Liberty Gas Storage [Member] | Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners									100.00%				100.00%

SIGNIFICANT ACCOUNTING POLIC_19

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Foreign currency transaction (losses) gains, net	$ (18)	$ (25)	$ 21

SIGNIFICANT ACCOUNTING POLIC_20

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details)	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2021MXN ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 23,000,000	$ 20,000,000	$ 32,000,000
Due from unconsolidated affiliates - noncurrent	637,000,000	780,000,000	742,000,000
Due to unconsolidated affiliates, noncurrent	(287,000,000)	(234,000,000)	(195,000,000)
Due to unconsolidated affiliates - current	0	(45,000,000)	(5,000,000)
Total facility	9,535,000,000
Due to/from Various Affiliates
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	0	$ (4,000,000)	(5,000,000)
LIBOR | ESJ JV
Related Party Transaction [Line Items]
Variable percentage rate		1.96%
Related party transaction rate		2.11%
LIBOR | TAG Pipeline Norte JV
Related Party Transaction [Line Items]
Variable percentage rate		2.90%
Related party transaction rate		3.16%
Sempra Infrastructure
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	(287,000,000)	$ (234,000,000)	(195,000,000)
Sempra Infrastructure | ESJ JV
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	0	85,000,000	0
Accrued interest receivable		1,000,000
Sempra Infrastructure | IMG JV
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	637,000,000	695,000,000	742,000,000
Due from affiliates, allowance for credit loss	1,000,000	3,000,000
Accrued interest receivable	2,000,000	2,000,000
Total facility	691,000,000			$ 14,200,000,000
Sempra Infrastructure | Due From Sempra Mexico
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	637,000,000	780,000,000	742,000,000
Sempra Infrastructure | TAG Pipeline Norte JV
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	0	0	(39,000,000)
Sempra Infrastructure | TAG Pipeline Norte JV | Other Long term Debt Currently Through December 2021
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	0	(41,000,000)	0
Sempra Infrastructure | TAG Pipeline Norte JV | Other Long term Debt Currently Through January 2024
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (69,000,000)	(68,000,000)	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure | TAG Pipeline Norte JV | Five Point Five Notes Due January 2025
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (21,000,000)	0	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure | TAG Pipeline Norte JV | Five Point Five Notes Due July 2025
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (20,000,000)	0	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure | TAG JV Notes
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (177,000,000)	(166,000,000)	(156,000,000)
Stated percentage rate	5.74%			5.74%
Sempra Infrastructure | Interbank Equilibrium Rate | IMG JV
Related Party Transaction [Line Items]
Variable percentage rate	2.20%
Related party transaction rate	8.06%
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ (97,000,000)	(64,000,000)	(53,000,000)
Total facility	1,500,000,000
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(40,000,000)	(38,000,000)	(37,000,000)
Income taxes due (from) Sempra Energy	19,000,000	0	130,000,000
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(48,000,000)	(21,000,000)	(10,000,000)
San Diego Gas and Electric Company [Member] | Due to/from Various Affiliates
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(9,000,000)	(5,000,000)	(6,000,000)
SoCalGas
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	49,000,000	22,000,000	11,000,000
Due to unconsolidated affiliates - current	(36,000,000)	(31,000,000)	(47,000,000)
Total facility	750,000,000
SoCalGas | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(36,000,000)	(31,000,000)	(45,000,000)
Income taxes due (from) Sempra Energy	6,000,000	(37,000,000)	152,000,000
SoCalGas | Due to/from Various Affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1,000,000	1,000,000	1,000,000
SoCalGas | Due to/from SDGE
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	48,000,000	21,000,000	10,000,000
SoCalGas | Other related parties
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ 0	$ 0	$ (2,000,000)

SIGNIFICANT ACCOUNTING POLIC_21

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2022MW	Dec. 31, 2021USD ($)MW	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Related Party Transaction [Line Items]
Related party revenue		$ 31	$ 37	$ 52
Related party cost of sales		11	45	50
Interest Income, Related Party		50	56	74
Interest Expense, Related Party		15	14	2
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Related party revenue		11	6	6
Related party cost of sales		$ 103	79	74
San Diego Gas and Electric Company [Member] | ESJ
Related Party Transaction [Line Items]
Power purchase agreement term		20 years
Generating capacity (in mw) | MW		155
San Diego Gas and Electric Company [Member] | ESJ | Subsequent Event
Related Party Transaction [Line Items]
Generating capacity (in mw) | MW	108
SoCalGas
Related Party Transaction [Line Items]
Related party revenue		$ 98	88	69
Related party cost of sales		$ 1	$ 0	$ 8
Minimum | Federal Funds Rate | California Utilities
Related Party Transaction [Line Items]
Variable percentage rate		13.00%
Maximum | Federal Funds Rate | California Utilities
Related Party Transaction [Line Items]
Variable percentage rate		20.00%
ESJ | Sempra Infrastructure | ESJ
Related Party Transaction [Line Items]
Ownership percentage in equity method investee		50.00%

SIGNIFICANT ACCOUNTING POLIC_22

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RESTRICTED NET ASSETS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Significant Restrictions of Subsidiaries [Line Items]
Undistributed earnings from equity method investments	$ 1,500	$ 1,100	$ 634
Sempra Texas Utilities | Oncor Holdings
Significant Restrictions of Subsidiaries [Line Items]
Plan percentage of capital structure allocated to equity	42.50%
Maximum ratio of indebtedness to total capitalization	0.65
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	57.50%
Sempra Texas Utilities | Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	80.25%
Sempra Infrastructure | Mexican Subsidiaries
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 193
Sempra Infrastructure | IEnova Pipelines
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	20
Sempra Infrastructure | SI Partners
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	6,800
Sempra Infrastructure | Cameron LNG JV
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	395
Sempra Infrastructure | TAG JV
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 66
Ownership percentage in equity method investee	50.00%
Consolidated Entities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 19,300
Unconsolidated Entities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	13,200
San Diego Gas and Electric Company [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	7,500
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 798
Plan percentage of capital structure allocated to equity	52.00%
SoCalGas
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 5,000
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 445
Plan percentage of capital structure allocated to equity	52.00%
California Utilities
Significant Restrictions of Subsidiaries [Line Items]
Maximum ratio of indebtedness to total capitalization	0.65
Sempra Texas Utilities | Sharyland Holdings, LP
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50.00%
Sempra Texas Utilities | Sharyland Utilities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 103
Maximum ratio of indebtedness to total capitalization	0.70
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	60.00%
Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 12,600

SIGNIFICANT ACCOUNTING POLIC_23

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER (EXPENSE) INCOME, NET (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Income [Line Items]
Allowance for equity funds used during construction	$ 133	$ 128	$ 94
Investment gains, net	50	41	61
(Losses) gains on interest rate and foreign exchange instruments, net	(28)	(67)	34
Foreign currency transaction (losses) gains, net	(18)	(25)	21
Non-service component of net periodic benefit cost	(67)	(102)	(132)
Interest on regulatory balancing accounts, net	6	14	14
Sundry, net	(18)	(37)	(15)
Total	58	(48)	77
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction	81	79	56
Non-service component of net periodic benefit cost	(13)	(20)	(20)
Interest on regulatory balancing accounts, net	6	9	13
Sundry, net	(10)	(16)	(10)
Total	64	52	39
SoCalGas
Other Income [Line Items]
Allowance for equity funds used during construction	48	41	34
Non-service component of net periodic benefit cost	(40)	(54)	(72)
Interest on regulatory balancing accounts, net	0	5	1
Sundry, net	(22)	(20)	(18)
Total	(14)	(28)	(55)
IMG JV
Other Income [Line Items]
Foreign currency transaction (losses) gains, net	$ (23)	$ (42)	$ 30

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 11,676	$ 10,310	$ 10,141
Utilities regulatory revenues	451	570	264
Other revenues	730	490	424
Total revenues	12,857	11,370	10,829
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10,540	9,455	9,184
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,136	855	957
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,969	5,796	5,596
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,707	4,514	4,545
Operating Segments | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,144	4,920	4,819
Utilities regulatory revenues	360	393	106
Other revenues	0	0	0
Total revenues	5,504	5,313	4,925
Operating Segments | San Diego Gas and Electric Company [Member] | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,144	4,920	4,819
Operating Segments | San Diego Gas and Electric Company [Member] | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments | San Diego Gas and Electric Company [Member] | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	790	692	587
Operating Segments | San Diego Gas and Electric Company [Member] | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,354	4,228	4,232
Operating Segments | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Utilities regulatory revenues	91	177	158
Other revenues	0	0	0
Total revenues	5,515	4,748	4,525
Operating Segments | SoCalGas | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Operating Segments | SoCalGas | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments | SoCalGas | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Operating Segments | SoCalGas | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,246	912	1,024
Utilities regulatory revenues	0	0	0
Other revenues	751	488	430
Total revenues	1,997	1,400	1,454
Operating Segments | Sempra Infrastructure | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	81	58	73
Operating Segments | Sempra Infrastructure | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,165	854	951
Operating Segments | Sempra Infrastructure | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	856	623	711
Operating Segments | Sempra Infrastructure | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	390	289	313
Operating Segments | Sempra Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Utilities regulatory revenues	0	0	0
Other revenues	0	0	5
Total revenues	0	0	10
Operating Segments | Sempra Renewables | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments | Sempra Renewables | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Operating Segments | Sempra Renewables | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments | Sempra Renewables | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(138)	(93)	(74)
Utilities regulatory revenues	0	0	0
Other revenues	(21)	2	(11)
Total revenues	(159)	(91)	(85)
Consolidating adjustments and Parent and other | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(109)	(94)	(75)
Consolidating adjustments and Parent and other | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(29)	1	1
Consolidating adjustments and Parent and other | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(101)	(90)	(69)
Consolidating adjustments and Parent and other | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (37)	$ (3)	$ (5)

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Dec. 31, 2021USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 6,112
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 368
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 367
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 365
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 362
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 361
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,289
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 83
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 63
Revenues to be recognized, period of recognition

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Liability [Roll Forward]
Beginning balance	$ (207)	$ (163)	$ (70)
Revenue from performance obligations satisfied during reporting period	52	4	2
Payments received in advance	(123)	(48)	(95)
Ending balance	(278)	(207)	(163)
Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Beginning balance	(52)	(4)
Ending balance	(116)	(52)	(4)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Beginning balance	(155)	(159)
Ending balance	(162)	(155)	(159)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(87)	(91)	0
Revenue from performance obligations satisfied during reporting period	4	4	1
Payments received in advance	0	0	(92)
Ending balance	(83)	(87)	(91)
San Diego Gas and Electric Company [Member] | Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Beginning balance	(4)	(4)
Ending balance	(4)	(4)	(4)
San Diego Gas and Electric Company [Member] | Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Beginning balance	(83)	(87)
Ending balance	$ (79)	$ (83)	$ (87)

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,977	$ 1,462	$ 1,184
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,886	1,447	1,163
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	19	12	16
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	3	5
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	70	0	0
San Diego Gas and Electric Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	751	583	405
San Diego Gas and Electric Company [Member] | Customers Under California Arrearage Payment Program
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	63
San Diego Gas and Electric Company [Member] | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	715	573	398
San Diego Gas and Electric Company [Member] | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	9	8	5
San Diego Gas and Electric Company [Member] | Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	2	2
San Diego Gas and Electric Company [Member] | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	25	0	0
SoCalGas
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,139	790	721
SoCalGas | Customers Under California Arrearage Payment Program
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	79
SoCalGas | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,084	786	710
SoCalGas | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	10	4	11
SoCalGas | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 45	$ 0	$ 0

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Amortization of regulatory asset	$ 10	$ 9	$ 7
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,479)	(1,500)	(1,908)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	358	139	108
Amortization of regulatory asset	5	4	3
San Diego Gas and Electric Company [Member] | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(50)	(53)	8
San Diego Gas and Electric Company [Member] | Deferred income taxes recoverable (refundable) in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	125	22	(108)
San Diego Gas and Electric Company [Member] | Pension and other postretirement benefit plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(7)	50	103
San Diego Gas and Electric Company [Member] | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,251)	(2,121)	(2,056)
San Diego Gas and Electric Company [Member] | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	62	56	45
San Diego Gas and Electric Company [Member] | Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 122	121	121
Amortization period	48 years
San Diego Gas and Electric Company [Member] | Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 77	72	102
San Diego Gas and Electric Company [Member] | Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	49	35	22
San Diego Gas and Electric Company [Member] | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	67	67	77
San Diego Gas and Electric Company [Member] | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(107)	(158)	(124)
San Diego Gas and Electric Company [Member] | 2019 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	56	111
San Diego Gas and Electric Company [Member] | Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	178	93	12
San Diego Gas and Electric Company [Member] | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	110	79	24
San Diego Gas and Electric Company [Member] | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	207	61	70
San Diego Gas and Electric Company [Member] | Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	119	72	(153)
San Diego Gas and Electric Company [Member] | Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,299)	(1,548)	(1,746)
SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	410	218	500
Amortization of regulatory asset	5	5	4
SoCalGas | Deferred income taxes recoverable (refundable) in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	44	(82)	(203)
SoCalGas | Pension and other postretirement benefit plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	51	417	400
SoCalGas | Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	31	37	44
SoCalGas | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(627)	(685)	(728)
SoCalGas | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	34	36	40
SoCalGas | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	339	335	295
SoCalGas | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(183)	(253)	(273)
SoCalGas | Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(146)	(56)	(118)
SoCalGas | 2019 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	202	400
SoCalGas | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	16	7	4
SoCalGas | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	42	(65)	(11)
SoCalGas | Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	142	75	(101)
SoCalGas | Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(257)	(32)	(251)
Sempra Infrastructure | Deferred income taxes recoverable (refundable) in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	77	80	83
Sempra Infrastructure | Other regulatory assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 0	$ 0	$ 6

REGULATORY MATTERS - SCHEDULE O

REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE AUTHORIZED REVENUE INCREASES (Details) - USD ($) $ in Millions	Sep. 26, 2019	May 31, 2021	Apr. 30, 2020
San Diego Gas and Electric Company [Member] | General Rate Case
General Rate Case [Line Items]
Tracked income tax expense liability			$ 86
SoCalGas | General Rate Case
General Rate Case [Line Items]
Tracked income tax expense liability			$ 89
2019 GRC FD | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	$ 1,990
2019 GRC FD | San Diego Gas and Electric Company [Member] | Electricity
General Rate Case [Line Items]
GRC revenue requirement	1,590
2019 GRC FD | San Diego Gas and Electric Company [Member] | Gas
General Rate Case [Line Items]
GRC revenue requirement	400
2019 GRC FD | SoCalGas
General Rate Case [Line Items]
GRC revenue requirement	2,770
2020 GRC FD | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 134
Percent increase (as a percent)	6.74%
2020 GRC FD | San Diego Gas and Electric Company [Member] | O&M
General Rate Case [Line Items]
Revenue increase	$ 20
Percent increase (as a percent)	2.64%
2020 GRC FD | San Diego Gas and Electric Company [Member] | Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 114
Percent increase (as a percent)	9.74%
2020 GRC FD | SoCalGas
General Rate Case [Line Items]
Revenue increase	$ 220
Percent increase (as a percent)	7.92%
2020 GRC FD | SoCalGas | O&M
General Rate Case [Line Items]
Revenue increase	$ 36
Percent increase (as a percent)	2.64%
2020 GRC FD | SoCalGas | Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 184
Percent increase (as a percent)	14.36%
2021 GRC FD | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 102
Percent increase (as a percent)	4.83%
2021 GRC FD | San Diego Gas and Electric Company [Member] | O&M
General Rate Case [Line Items]
Revenue increase	$ 19
Percent increase (as a percent)	2.47%
2021 GRC FD | San Diego Gas and Electric Company [Member] | Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 83
Percent increase (as a percent)	6.47%
2021 GRC FD | SoCalGas
General Rate Case [Line Items]
Revenue increase	$ 150
Percent increase (as a percent)	5.00%
2021 GRC FD | SoCalGas | O&M
General Rate Case [Line Items]
Revenue increase	$ 34
Percent increase (as a percent)	2.40%
2021 GRC FD | SoCalGas | Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 116
Percent increase (as a percent)	7.93%
2019 GRC FD - 2022 Requirement | San Diego Gas and Electric Company [Member] | General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 87
Percent increase (as a percent)		3.92%
2019 GRC FD - 2022 Requirement | SoCalGas | General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 142
Percent increase (as a percent)		4.53%
2019 GRC FD - 2023 Requirement | San Diego Gas and Electric Company [Member] | General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 86
Percent increase (as a percent)		3.70%
2019 GRC FD - 2023 Requirement | SoCalGas | General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 130
Percent increase (as a percent)		3.97%

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL & FERC RATES (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended				36 Months Ended
	Oct. 31, 2019	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2022	Jan. 01, 2022	Aug. 31, 2021
California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate, variable rate (as a percent)					1.00%
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Minimum common equity ratio (as a percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
FERC requirement, additional basis spread	0.50%
FERC, revenue requirement				$ 12
San Diego Gas and Electric Company [Member] | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)		4.498%
Common equity ratio (as a percent)					52.00%			54.00%
Authorized ROE (as a percent)					10.20%			10.55%
Cost of debt (as a percent)					4.59%			3.84%
Proposed return on base rate (as a percent)					7.55%			7.46%
CCM benchmark rate, percentage below (as a percent)			1.17%
San Diego Gas and Electric Company [Member] | Federal Energy Regulatory Commission
Public Utilities, General Disclosures [Line Items]
FERC, revenue requirement				$ 17
San Diego Gas and Electric Company [Member] | Common Equity | Federal Energy Regulatory Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				10.05%
SoCalGas | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)		4.029%
Forecast | San Diego Gas and Electric Company [Member] | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Authorized weighting, total (as a percent)						100.00%
Weighted return on rate base, total (as a percent)						7.55%
Authorized ROE (as a percent)							9.62%
Forecast | San Diego Gas and Electric Company [Member] | Authorized weighting | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						45.25%
Forecast | San Diego Gas and Electric Company [Member] | Authorized weighting | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						2.75%
Forecast | San Diego Gas and Electric Company [Member] | Authorized weighting | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						52.00%
Forecast | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						4.59%
Forecast | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						6.22%
Forecast | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						10.20%
Forecast | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						2.08%
Forecast | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						0.17%
Forecast | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						5.30%
Forecast | SoCalGas | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Authorized weighting, total (as a percent)						100.00%
Weighted return on rate base, total (as a percent)						7.30%
Forecast | SoCalGas | Authorized weighting | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						45.60%
Forecast | SoCalGas | Authorized weighting | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						2.40%
Forecast | SoCalGas | Authorized weighting | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						52.00%
Forecast | SoCalGas | Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						4.23%
Forecast | SoCalGas | Return on Rate Base | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						6.00%
Forecast | SoCalGas | Return on Rate Base | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						10.05%
Forecast | SoCalGas | Weighted Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						1.93%
Forecast | SoCalGas | Weighted Return on Rate Base | California Public Utilities Commission | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						0.14%
Forecast | SoCalGas | Weighted Return on Rate Base | California Public Utilities Commission | Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						5.23%

REGULATORY MATTERS - BILLING PR

REGULATORY MATTERS - BILLING PRACTICES (Details) - California Public Utilities Commission - USD ($)	Feb. 03, 2022	Feb. 28, 2022	Dec. 31, 2020
Energy Efficiency Program Inquiry
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue			$ 51,000,000
Litigation fines			6,000,000
Litigation fines, after tax			44,000,000
SoCalGas | Energy Efficiency and Advocacy | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue	$ 10,000,000	$ 150,000
San Diego Gas and Electric Company [Member] | Energy Efficiency Program Inquiry
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue			51,000,000
Litigation fines			6,000,000
Litigation fines, after tax			$ 44,000,000

ACQUISTIONS, DIVESTITURES AND_3

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Acquisitions (Details) $ in Millions	Jan. 15, 2022MW	Mar. 19, 2021USD ($)MW	May 16, 2019USD ($)	Mar. 31, 2021	Mar. 18, 2021	Dec. 31, 2020	May 31, 2019
Sharyland Holdings, LP
Business Acquisition [Line Items]
Acquired percentage interest			50.00%
Consideration transferred			$ 95
Post closing adjustments			$ 7
Sharyland Holdings, LP | Sharyland Utilities | Sharyland Holdings, LP
Business Acquisition [Line Items]
Acquired percentage interest			100.00%
Sempra Texas Utilities | Sharyland Holdings, LP
Business Acquisition [Line Items]
Acquired percentage interest							50.00%
IEnova | Sempra Infrastructure | ESJ Asset Acquisition
Business Acquisition [Line Items]
Purchase price		$ 65
Cash acquired		14
Debt assumed		277
Related party note payable assumed		$ 94
Subsequent acquisition, percentage		100.00%
Equity interest in acquiree, fair value		$ 34
Assets acquired		458
Liabilities assumed		$ 345
Generating capacity (in mw) | MW		155
Intangible assets acquired		$ 190
Weighted average life of finite-lived intangible acquired		14 years
Saavi Energia | ESJ
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners		50.00%
Sempra Infrastructure | ESJ
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners				50.00%	50.00%	50.00%
Subsequent Event | IEnova | Sempra Infrastructure | ESJ Asset Acquisition
Business Acquisition [Line Items]
Generating capacity (in mw) | MW	108

ACQUISTIONS, DIVESTITURES AND_4

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Divestitures (Details) - USD ($) $ in Millions	Apr. 22, 2019	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 07, 2019	Jan. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (loss) on sale of assets			$ 36	$ (3)	$ 63
Sempra Infrastructure | Mississippi Hub And Bay Gas | Disposal Group Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale						$ 322
Sempra Infrastructure | Other Non-Utility assets | Disposal Group Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale							$ 5
Sempra Renewables | Wind Generation Projects | Disposal Group Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 569
Gain (loss) on sale of assets	61
Gain on sale of assets, after tax and NCI	$ 45
Parent and Other | PXISE Energy Solutions LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale		$ 38	$ 38
Transaction costs		4
Gain on sale		36
Gain on sale of assets, net of tax		$ 26

ACQUISTIONS, DIVESTITURES AND_5

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Discontinued Operations (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Jun. 30, 2020	Apr. 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]
Income from discontinued operations, net of income tax			$ 0	$ 1,850	$ 363
Earnings attributable to noncontrolling interests			0	(10)	(35)
Earnings from discontinued operations attributable to common shares			0	1,840	328
Restricted cash			0	0	75
Assets held for sale in discontinued operations			0	0	445
Noncurrent assets			0	0	3,513
Liabilities held for sale in discontinued operations			0	0	444
Noncurrent liabilities			$ 0	0	1,052
Discontinued Operations, Held-for-sale | Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
After tax gain on sale				2,899	0
Revenues				570	1,614
Cost of sales				(364)	(1,012)
Operating expenses				(66)	(159)
Interest and other				(3)	(11)
Income before income taxes and equity earnings				3,036	432
Income tax expense				(1,186)	(72)
Equity earnings				0	3
Income from discontinued operations, net of income tax				1,850	363
Earnings from discontinued operations attributable to common shares				1,840	328
Cash and cash equivalents				4,600	74
Restricted cash					1
Accounts receivable, net					303
Due from unconsolidated affiliates					2
Inventories					36
Other current assets					29
Assets held for sale in discontinued operations					445
Due from unconsolidated affiliates					54
Goodwill and other intangible assets					801
Property, plant and equipment, net					2,618
Other noncurrent assets					40
Noncurrent assets					3,513
Short-term debt					52
Accounts payable					201
Current portion of long-term debt and finance leases					85
Other current liabilities					106
Liabilities held for sale in discontinued operations					444
Long-term debt and finance leases					702
Deferred income taxes					284
Other noncurrent liabilities					66
Noncurrent liabilities					$ 1,052
Cumulative foreign currency translation adjustments				$ 645
Discontinued Operations, Held-for-sale | Sempra South American Utilities | Luz Del Sur
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale		$ 3,549
Pretax gain on sale		2,271
After tax gain on sale		$ 1,499
Discontinued Operations, Held-for-sale | Sempra South American Utilities | Chilquinta Energia
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 2,216
Pretax gain on sale	628
After tax gain on sale	$ 248
Luz Del Sur | Discontinued Operations, Held-for-sale | Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			83.60%
Eletrans | Discontinued Operations, Held-for-sale | Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)	50.00%
Chilquinta Energia | Discontinued Operations, Held-for-sale | Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			100.00%
PXISE Energy Solutions LLC | Parent and Other
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			80.00%

INVESTMENTS IN UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 18, 2021
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 12,947	$ 12,440	$ 11,519
Other investments	1,525	1,388	2,103
Goodwill	1,602	1,602	1,602
Earnings (losses) recorded before income tax	614	294	30
Earnings recorded net of income tax	729	721	550
Total equity earnings	1,343	1,015	580
Distributions from investments	1,360	1,462	256
Total other equity method investments
Schedule of Equity Method Investments [Line Items]
Other investments	1,525	1,387	2,097
Other
Schedule of Equity Method Investments [Line Items]
Other investments	0	1	6
R B S Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Total equity earnings	50	(100)
Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 688	$ 286	$ 246
Sempra Texas Utilities | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%	100.00%	100.00%
Equity method investment	$ 12,947	$ 12,440	$ 11,519
Difference between carrying amount of equity method investment and underlying equity	2,844	2,833	2,823
Goodwill	2,868	2,868	2,868
Equity method investment, difference between carrying amount and underlying equity, aoci	69	69	69
Difference between carrying amount and underlying equity, tax sharing liability	93	104	114
Earnings recorded net of income tax	$ 617	$ 577	$ 526
Sempra Texas Utilities | Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%	50.00%
Equity method investment	$ 100	$ 102	$ 100
Difference between carrying amount of equity method investment and underlying equity	42
Earnings (losses) recorded before income tax	5	3	2
Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 672	1,176	2
Sempra Infrastructure | ESJ
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount of equity method investment and underlying equity		$ 12	$ 12
Ownership percentage held by noncontrolling owners		50.00%		50.00%	50.00%
Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%	50.20%	50.20%
Other investments	$ 514	$ 433	$ 1,256
Difference between carrying amount of equity method investment and underlying equity	276	259	263
Earnings (losses) recorded before income tax	$ 559	$ 391	$ 24
Sempra Infrastructure | ESJ JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%	50.00%
Other investments	$ 0	$ 34	$ 39
Earnings recorded net of income tax	$ 2	$ 5	$ 2
Sempra Infrastructure | IMG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40.00%	40.00%	40.00%
Other investments	$ 523	$ 440	$ 337
Difference between carrying amount of equity method investment and underlying equity	5
Earnings recorded net of income tax	$ 83	$ 103	$ 9
Sempra Infrastructure | TAG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%	50.00%
Other investments	$ 388	$ 378	$ 365
Difference between carrying amount of equity method investment and underlying equity	130
Earnings recorded net of income tax	27	36	13
Sempra Renewables
Schedule of Equity Method Investments [Line Items]
Distributions from investments	0	0	1
Sempra Renewables | Wind Assets
Schedule of Equity Method Investments [Line Items]
Earnings (losses) recorded before income tax	0	0	5
Parent and other
Schedule of Equity Method Investments [Line Items]
Distributions from investments	0	0	7
Parent and other | Other
Schedule of Equity Method Investments [Line Items]
Earnings (losses) recorded before income tax	0	0	(1)
Parent and other | R B S Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Earnings (losses) recorded before income tax	$ 50	$ (100)	$ 0

INVESTMENTS IN UNCONSOLIDATED_4

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details)	May 16, 2019USD ($)	Jun. 30, 2021USD ($)	Jul. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2021USD ($)MTBcf	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Mar. 19, 2021	Mar. 18, 2021	May 31, 2019	Jun. 30, 2015USD ($)	Nov. 30, 2014USD ($)
Schedule of Equity Method Investments [Line Items]
Undistributed earnings from equity method investments				$ 634,000,000	$ 1,500,000,000	$ 1,100,000,000	$ 634,000,000
Undistributed earnings, equity method investments, over 50 percent owned					1,100,000,000
Interest costs capitalized					217,000,000	202,000,000	183,000,000
Equitization of long-term debt for deficit held by NCI					0	22,000,000	0
Return on investments					366,000,000	761,000,000	9,000,000
Equity earnings					1,343,000,000	1,015,000,000	580,000,000
Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Cash contributed to fund the acquisition				$ 1,067,000,000			$ 1,067,000,000
R B S Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Equity earnings					$ 50,000,000	$ (100,000,000)
Cameron LNG
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee					50.20%
Indirect economic and beneficial and ownership interest after financial completion					10.00%
Sempra Texas Utilities | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				100.00%	100.00%	100.00%	100.00%
Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Current guarantor obligations					$ 7,000,000
Sempra Infrastructure | IMG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee					40.00%
Transportation service contract term					35 years
Sempra Infrastructure | Cameron LNG
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments					$ 2,000,000	$ 54,000,000	$ 77,000,000
Project capacity | MT					13.9
Proved undeveloped reserve | MT					12
Proved undeveloped reserve per day | Bcf					1.7
Interest costs capitalized						33,000,000
Debt amount					$ 7,400,000,000
Equitization of long-term debt for deficit held by NCI				$ 3,000,000,000
Fixed percentage interest rate					3.39%
Notional amount of derivatives											$ 1,500,000,000	$ 3,700,000,000
Derivative amount terminated				$ 790,000,000
Effective fixed rate (as a percent)				3.26%
Weighted-average all-in cost of loans outstanding (as a percent)					3.69%
Sempra Infrastructure | Cameron LNG | Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Proceeds from related parties			$ 1,500,000,000
Debt covenant, liability cap (as a percent)					130.00%
Debt covenant, liability cap amount					$ 979,000,000
Sempra Infrastructure | Cameron LNG | Corporate Joint Venture | Promissory Note for SDSRA Distribution
Schedule of Equity Method Investments [Line Items]
Cash dividends received		$ 165,000,000
Sempra Infrastructure | Cameron LNG | Corporate Joint Venture | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related parties			$ 753,000,000
Return on investments					753,000,000
Sempra Infrastructure | Cameron LNG | Corporate Joint Venture | Deferred Credits and Other | Promissory Note for SDSRA Distribution
Schedule of Equity Method Investments [Line Items]
Guaranty liability		$ 22,000,000			$ 22,000,000
Sempra Infrastructure | LIBOR | Cameron LNG
Schedule of Equity Method Investments [Line Items]
Fixed percentage interest rate											3.32%	3.19%
Weighted average rate prior to project completion					0.98%
Weighted average rate after project completion					1.22%
Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest	50.00%
Payments to acquire equity method investments	$ 95,000,000
Post-closing adjustments	$ 7,000,000
Cash invested in equity method investment							3,000,000
Sharyland Holdings, LP | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest										50.00%
ESJ | Sempra Infrastructure | IEnova
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest								50.00%
Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments					$ 566,000,000	$ 632,000,000	$ 1,587,000,000
Oncor Holdings | Sempra Texas Holdings Corp | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity					100.00%
Oncor Electric Delivery Company LLC | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners					80.25%
Cameron LNG | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity					50.20%
ESJ | ESJ | Sempra Infrastructure | IEnova
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners									50.00%

INVESTMENTS IN UNCONSOLIDATED_5

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 18, 2021
Schedule of Equity Method Investments [Line Items]
Net income	$ 1,463	$ 4,105	$ 2,362
Current assets	4,375	4,511	3,339
Current liabilities	10,035	6,839	9,150
Other
Schedule of Equity Method Investments [Line Items]
Operating revenue	2,721	2,341	798
Operating expense	(719)	(706)	(372)
Operating Income	2,002	1,635	426
Interest expense	(548)	(514)	(401)
Net income	1,388	1,132	85
Current assets	788	1,035	1,124
Noncurrent assets	14,686	15,304	15,039
Current liabilities	1,230	1,342	1,232
Noncurrent liabilities	11,807	12,863	11,438
Oncor Holdings | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Operating revenue	4,764	4,511	4,347
Operating expense	(3,397)	(3,224)	(3,135)
Operating Income	1,367	1,287	1,212
Interest expense	(413)	(405)	(375)
Income tax expense	(163)	(146)	(131)
Net income	760	703	643
Noncontrolling interest held by TTI	(152)	(141)	(129)
Equity Method Investment, Summarized Financial Information, Net Income (Loss), Attributable To Controlling Interest	608	562	514
Current assets	1,039	1,045	913
Noncurrent assets	29,481	28,022	26,012
Current liabilities	2,220	1,120	1,626
Noncurrent liabilities	15,281	15,611	14,125
Noncontrolling interest held by TTI	$ 2,916	$ 2,737	$ 2,473
Sempra Infrastructure | ESJ
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners		50.00%		50.00%	50.00%

DEBT AND CREDIT FACILITIES - SH

DEBT AND CREDIT FACILITIES - SHORT TERM DEBT DETAILS (Details)	1 Months Ended		12 Months Ended
	Nov. 30, 2021USD ($)lender	Jun. 30, 2021USD ($)	Dec. 31, 2021USD ($)lender	Sep. 30, 2021USD ($)
Line of Credit Facility [Line Items]
Total facility			$ 9,535,000,000
Number of lenders | lender			23
Lenders, percent of facility			6.00%
Line of credit			$ 749,000,000
Letters of credit outstanding			682,000,000
Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility			470,000,000
Line of credit			321,000,000
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Total facility			470,000,000
Sempra Energy
Line of Credit Facility [Line Items]
Total facility			3,185,000,000
Committed lines of credit, capacity for issuance of letters of credit			200,000,000
Line of credit, increase limit			500,000,000
Line of credit			0
Sempra Energy | Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Total facility			1,250,000,000
Line of credit			0
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Total facility			1,500,000,000
Committed lines of credit, capacity for issuance of letters of credit			100,000,000
Line of credit, increase limit			250,000,000
Line of credit			0
San Diego Gas and Electric Company [Member] | Term Loan Due 2022 | Secured Debt [Member]
Line of Credit Facility [Line Items]
Variable percentage rate		0.625%
Debt amount		$ 375,000,000	375,000,000
SoCalGas
Line of Credit Facility [Line Items]
Total facility			750,000,000
Committed lines of credit, capacity for issuance of letters of credit			100,000,000
Line of credit, increase limit			250,000,000
Line of credit			$ 0
Sempra U.S.
Line of Credit Facility [Line Items]
Maximum ratio of indebtedness to total capitalization (as a percent)			65.00%
SI Partners
Line of Credit Facility [Line Items]
Total facility	$ 1,000,000,000		$ 1,000,000,000
Number of lenders | lender	12
Lenders, percent of facility	8.33%
Committed lines of credit, capacity for issuance of letters of credit	$ 200,000,000
Term of contract	3 years
Line of credit			0
Maximum adjustment EBITDA allowed	5.25
SI Partners | Swingline Sub-Limit
Line of Credit Facility [Line Items]
Line of credit	$ 100,000,000
IEnova | Foreign Line of Credit | Foreign Committed Lines of Credit, Due September 2021
Line of Credit Facility [Line Items]
Total facility			$ 350,000,000	$ 280,000,000
IEnova | Foreign Line of Credit | Foreign Committed Lines of Credit, Due September 2021 | LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate			0.54%
IEnova | Foreign Line of Credit | Foreign Committed Lines of Credit, Due February 2024
Line of Credit Facility [Line Items]
Total facility			$ 1,500,000,000
Number of lenders | lender			10
IEnova | Foreign Line of Credit | Foreign Committed Lines of Credit, Due February 2024 | LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate			0.80%

DEBT AND CREDIT FACILITIES - SC

DEBT AND CREDIT FACILITIES - SCHEDULES OF SUMMARIES OF LINES OF CREDIT (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Nov. 30, 2021
Line of Credit Facility [Line Items]
Total facility	$ 9,535,000,000
Line of credit outstanding	(749,000,000)
Available unused credit	6,760,000,000
Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(2,026,000,000)
Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	470,000,000
Line of credit outstanding	(321,000,000)
Available unused credit	149,000,000
Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	682,000,000
Sempra Energy
Line of Credit Facility [Line Items]
Total facility	3,185,000,000
Line of credit outstanding	0
Available unused credit	1,945,000,000
Sempra Energy | Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Total facility	1,250,000,000
Line of credit outstanding	0
Available unused credit	1,250,000,000
Sempra Energy | Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(1,240,000,000)
Sempra Energy | Commercial paper | Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Line of credit outstanding	0
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Total facility	1,500,000,000
Line of credit outstanding	0
Available unused credit	1,099,000,000
San Diego Gas and Electric Company [Member] | Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(401,000,000)
San Diego Gas and Electric Company [Member] | Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	15,000,000
SoCalGas
Line of Credit Facility [Line Items]
Total facility	750,000,000
Line of credit outstanding	0
Available unused credit	365,000,000
SoCalGas | Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(385,000,000)
SoCalGas | Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	15,000,000
SI Partners
Line of Credit Facility [Line Items]
Total facility	1,000,000,000	$ 1,000,000,000
Line of credit outstanding	0
Available unused credit	1,000,000,000
SI Partners | Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova | IEnova Committed Line Of Credit Due 2023
Line of Credit Facility [Line Items]
Total facility	350,000,000
Line of credit outstanding	(350,000,000)
Available unused credit	0
IEnova | IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Total facility	1,500,000,000
Line of credit outstanding	(399,000,000)
Available unused credit	1,101,000,000
IEnova | Commercial paper | IEnova Committed Line Of Credit Due 2023
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova | Commercial paper | IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Sempra Infrastructure | Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	473,000,000
Parent and Other | Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	179,000,000
Foreign Uncommitted Revolving Credit Facility September 2022 | IEnova | Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	250,000,000
Line of credit outstanding	(250,000,000)
Available unused credit	$ 0
Foreign Uncommitted Revolving Credit Facility September 2022 | IEnova | Foreign Line of Credit | LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	0.10%
Foreign Uncommitted Revolving Credit Facility Due August 2023 | ECA LNG Phase 1 | Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 100,000,000
Line of credit outstanding	(63,000,000)
Available unused credit	$ 37,000,000
Foreign Uncommitted Revolving Credit Facility Due August 2023 | ECA LNG Phase 1 | Foreign Line of Credit | LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	1.05%
Foreign Uncommitted Revolving Credit Facility Due October 2023 | IEnova | Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 100,000,000
Line of credit outstanding	(8,000,000)
Available unused credit	$ 92,000,000
Foreign Uncommitted Revolving Credit Facility Due October 2023 | IEnova | Foreign Line of Credit | LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	0.52%
Foreign Uncommitted Revolving Credit Facility Due October 2023-2 | IEnova | Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 20,000,000
Line of credit outstanding	0
Available unused credit	$ 20,000,000

DEBT AND CREDIT FACILITIES - _2

DEBT AND CREDIT FACILITIES - SCHEDULE OF WEIGHTED-AVERAGE INTEREST RATES (Details)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Sempra
Line of Credit Facility [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	0.60%	0.83%	2.31%
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	0.65%	0.00%	1.97%
SoCalGas
Line of Credit Facility [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	0.21%	0.14%	1.86%

DEBT AND CREDIT FACILITIES - _3

DEBT AND CREDIT FACILITIES - SCHEDULE OF LONG-TERM DEBT INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Nov. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term lease liabilities	$ 1,292		$ 1,294	$ 1,263
Finance lease obligations	1,335		1,330	1,289
Current portion of long-term debt	(106)		(1,540)	(1,526)
Long-term debt and finance leases	21,068		21,781	20,785
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Gross long-term debt	6,417		6,053	5,140
Long-term lease liabilities	1,242		1,250	1,250
Long term debt and lease obligations, including current maturities	7,691		7,529	6,410
Finance lease obligations	1,274		1,276	1,270
Current portion of long-term debt	(49)		(611)	(56)
Unamortized discount on long-term debt	(17)		(13)	(12)
Unamortized debt issuance costs	(44)		(39)	(36)
Total debt and lease obligations	7,581		6,866	6,306
Long-term debt and finance leases	7,581		$ 6,866	6,306
San Diego Gas and Electric Company [Member] | 3% August 15, 2021
Debt Instrument [Line Items]
Stated percentage rate			3.00%
Gross long-term debt	$ 0		$ 350	350
San Diego Gas and Electric Company [Member] | 1.914% payable 2015 through February 2022
Debt Instrument [Line Items]
Stated percentage rate	1.914%
Gross long-term debt	$ 17		53	89
San Diego Gas and Electric Company [Member] | 3.6% September 1, 2023
Debt Instrument [Line Items]
Stated percentage rate	3.60%
Gross long-term debt	$ 450		450	450
San Diego Gas and Electric Company [Member] | 2.5% May 15, 2026
Debt Instrument [Line Items]
Stated percentage rate	2.50%
Gross long-term debt	$ 500		500	500
San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due June 2026
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 250		250	250
San Diego Gas and Electric Company [Member] | 1.7% October 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	1.70%
Gross long-term debt	$ 800		800	$ 0
San Diego Gas and Electric Company [Member] | 5.875% January and February 2034(1)
Debt Instrument [Line Items]
Stated percentage rate				5.875%
Gross long-term debt	$ 0		0	$ 176
San Diego Gas and Electric Company [Member] | 5.35% May 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250	250
San Diego Gas and Electric Company [Member] | 6.125% September 15, 2037
Debt Instrument [Line Items]
Stated percentage rate	6.125%
Gross long-term debt	$ 250		250	$ 250
San Diego Gas and Electric Company [Member] | 4% May 1, 2039(1)
Debt Instrument [Line Items]
Stated percentage rate				4.00%
Gross long-term debt	$ 0		0	$ 75
San Diego Gas and Electric Company [Member] | 6% June 1, 2039
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 300		300	300
San Diego Gas and Electric Company [Member] | 5.35% May 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250	250
San Diego Gas and Electric Company [Member] | 4.5% August 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	4.50%
Gross long-term debt	$ 500		500	500
San Diego Gas and Electric Company [Member] | 3.95% November 15, 2041
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 250		250	250
San Diego Gas and Electric Company [Member] | 4.3% April 1, 2042
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 250		250	250
San Diego Gas and Electric Company [Member] | 3.75% June 1, 2047
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 400		400	400
San Diego Gas and Electric Company [Member] | 4.15% May 15, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.15%
Gross long-term debt	$ 400		400	400
San Diego Gas and Electric Company [Member] | 4.1% June 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.10%
Gross long-term debt	$ 400		400	400
San Diego Gas and Electric Company [Member] | 3.32% April 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.32%
Gross long-term debt	$ 400		400	0
San Diego Gas and Electric Company [Member] | 2.95% August 15, 2051
Debt Instrument [Line Items]
Stated percentage rate	2.95%
Gross long-term debt	$ 750		0	0
San Diego Gas and Electric Company [Member] | Purchased-power contracts
Debt Instrument [Line Items]
Long-term lease liabilities	1,217		1,237	1,255
San Diego Gas and Electric Company [Member] | Other
Debt Instrument [Line Items]
Long-term lease liabilities	57		39	15
San Diego Gas and Electric Company [Member] | Other Long-term Debt
Debt Instrument [Line Items]
Long term debt and lease obligations, including current maturities	1,274		$ 1,476	1,270
San Diego Gas and Electric Company [Member] | Other Long Term Debt, Variable Rate Notes Due March 2021 [Member]
Debt Instrument [Line Items]
Stated percentage rate			0.95%
Gross long-term debt	0		$ 200	0
SoCalGas
Debt Instrument [Line Items]
Gross long-term debt	4,450		4,450	3,800
Long-term lease liabilities	50		44	13
Long term debt and lease obligations, including current maturities	4,820		4,813	3,828
Finance lease obligations	61		54	19
Finance lease obligations and other long term debt	370		363	28
Current portion of long-term debt	(11)		(10)	(6)
Unamortized discount on long-term debt	(7)		(8)	(7)
Unamortized debt issuance costs	(29)		(32)	(27)
Total debt and lease obligations	4,773		4,763	3,788
Long-term debt and finance leases	$ 4,773		4,763	3,788
SoCalGas | First Mortgage Bonds Due June 2026
Debt Instrument [Line Items]
Stated percentage rate	2.60%
Gross long-term debt	$ 500		500	500
SoCalGas | 3.15% September 15, 2024
Debt Instrument [Line Items]
Stated percentage rate	3.15%
Gross long-term debt	$ 500		500	500
SoCalGas | 3.2% June 15, 2025
Debt Instrument [Line Items]
Stated percentage rate	3.20%
Gross long-term debt	$ 350		350	350
SoCalGas | 2.55% February 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	2.55%
Gross long-term debt	$ 650		650	0
SoCalGas | 5.75% November 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 250		250	250
SoCalGas | 5.125% November 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.125%
Gross long-term debt	$ 300		300	300
SoCalGas | 3.75% September 15, 2042
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 350		350	350
SoCalGas | 4.45% March 15, 2044
Debt Instrument [Line Items]
Stated percentage rate	4.45%
Gross long-term debt	$ 250		250	250
SoCalGas | 4.125% June 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.125%
Gross long-term debt	$ 400		400	400
SoCalGas | 4.3% January 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 550		550	550
SoCalGas | 3.95% February 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 350		350	350
SoCalGas | Notes at variable rates (0.55% at December 31, 2021) September 14, 2023(1)
Debt Instrument [Line Items]
Stated percentage rate	0.55%
Gross long-term debt	$ 300		300	0
SoCalGas | 1.875% Notes May 14, 2026(1)
Debt Instrument [Line Items]
Stated percentage rate	1.875%
Gross long-term debt	$ 4		4	4
SoCalGas | 5.67% Notes January 18, 2028(2)
Debt Instrument [Line Items]
Stated percentage rate	5.67%
Gross long-term debt	$ 5		5	$ 5
Sempra Energy | 2.4% Notes February 1, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.40%
Gross long-term debt	0		0	$ 500
Sempra Energy | 2.4% Notes March 15, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.40%
Gross long-term debt	0		0	$ 500
Sempra Energy | 2.85% Notes November 15, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.85%
Gross long-term debt	0		0	$ 400
Sempra Energy | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instrument [Line Items]
Gross long-term debt	0		0	700
Sempra Energy | Other Long Term Debt, Variable Rate Notes Due March 2021 [Member]
Debt Instrument [Line Items]
Gross long-term debt	0		$ 850	850
Fixed interest rate after floating to fixed interest rate swaps			3.069%
Sempra Energy | 2.875% Notes October 1, 2022
Debt Instrument [Line Items]
Stated percentage rate			2.875%
Gross long-term debt	0		$ 500	500
Sempra Energy | 2.9% Notes February 1, 2023
Debt Instrument [Line Items]
Stated percentage rate			2.90%
Gross long-term debt	0		$ 500	500
Sempra Energy | 4.05% Notes December 1, 2023
Debt Instrument [Line Items]
Stated percentage rate			4.05%
Gross long-term debt	0		$ 500	500
Sempra Energy | 3.55% Notes June 15, 2024
Debt Instrument [Line Items]
Stated percentage rate			3.55%
Gross long-term debt	0		$ 500	500
Sempra Energy | 3.75% Notes November 15, 2025
Debt Instrument [Line Items]
Stated percentage rate			3.75%
Gross long-term debt	$ 0		$ 350	350
Sempra Energy | 3.25% Notes June 15, 2027
Debt Instrument [Line Items]
Stated percentage rate	3.25%
Gross long-term debt	$ 750		750	750
Sempra Energy | 3.4% Notes February 1, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.40%
Gross long-term debt	$ 1,000		1,000	1,000
Sempra Energy | 3.8% Notes February 1, 2038
Debt Instrument [Line Items]
Stated percentage rate	3.80%
Gross long-term debt	$ 1,000		1,000	1,000
Sempra Energy | 6% Notes October 15, 2039
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 750		750	750
Sempra Energy | 4% Notes February 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.00%
Gross long-term debt	$ 800		800	800
Sempra Energy | 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instrument [Line Items]
Stated percentage rate	4.125%	4.125%
Gross long-term debt	$ 1,000		0	0
Sempra Energy | 5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 758		758	758
Sempra Infrastructure
Debt Instrument [Line Items]
Gross long-term debt	$ 8,923		11,247	12,298
Sempra Infrastructure | 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013)
Debt Instrument [Line Items]
Stated percentage rate	6.30%
Gross long-term debt	$ 189		197	207
Fixed interest rate after floating to fixed interest rate swaps	4.124%
Sempra Infrastructure | Loan at variable rates (2.93% at December 31, 2021) December 9, 2025
Debt Instrument [Line Items]
Stated percentage rate	2.93%
Gross long-term debt	$ 341		17	0
Sempra Infrastructure | Notes at 2.87% to 3.51% October 1, 2026(1)
Debt Instrument [Line Items]
Gross long-term debt	0		0	$ 22
Sempra Infrastructure | Notes at 2.87% to 3.51% October 1, 2026(1) | Minimum
Debt Instrument [Line Items]
Stated percentage rate				2.87%
Sempra Infrastructure | Notes at 2.87% to 3.51% October 1, 2026(1) | Maximum
Debt Instrument [Line Items]
Stated percentage rate				3.51%
Sempra Infrastructure | Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets(2)
Debt Instrument [Line Items]
Gross long-term debt	$ 154		196	$ 237
Fixed interest rate after floating to fixed interest rate swaps	5.13%
Sempra Infrastructure | 3.75% Notes January 14, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 300		300	300
Sempra Infrastructure | Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets
Debt Instrument [Line Items]
Gross long-term debt	0		$ 398	423
Sempra Infrastructure | Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets | Weighted Average
Debt Instrument [Line Items]
Stated percentage rate			6.87%
Gross long-term debt			$ 234
Sempra Infrastructure | Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)
Debt Instrument [Line Items]
Gross long-term debt	0		0	11
Sempra Infrastructure | Other Long-term Debt, Variable Rate Payable Through November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 200		200	200
Fixed interest rate after floating to fixed interest rate swaps	4.0275%
Sempra Infrastructure | Other Long Term Debt 2.9% Loan Due 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 241		241	0
Sempra Infrastructure | Other Long-term Debt, Variable Rate Loan Due November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 100		100	0
Fixed interest rate after floating to fixed interest rate swaps	2.38%
Sempra Infrastructure | 4.875% Notes January 14, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.875%
Gross long-term debt	$ 540		540	540
Sempra Infrastructure | Other Long-term Debt, 4.75% Notes Due September 2051
Debt Instrument [Line Items]
Stated percentage rate	4.75%
Gross long-term debt	$ 800		800	0
Other Sempra
Debt Instrument [Line Items]
Current portion of long-term debt	(46)		(919)	(1,464)
Unamortized discount on long-term debt	(65)		(55)	(35)
Unamortized debt issuance costs	(98)		(121)	(108)
Long-term debt and finance leases	$ 8,714		$ 10,152	$ 10,691
LIBOR | Sempra Energy | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instrument [Line Items]
Stated percentage rate				2.50%
LIBOR | Sempra Infrastructure | Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets
Debt Instrument [Line Items]
Stated percentage rate			3.45%
Gross long-term debt			$ 34
LIBOR | Sempra Infrastructure | Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets | Weighted Average
Debt Instrument [Line Items]
Gross long-term debt			$ 130
Fixed interest rate after floating to fixed interest rate swaps			6.54%
LIBOR | Sempra Infrastructure | Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)
Debt Instrument [Line Items]
Stated percentage rate				5.75%

DEBT AND CREDIT FACILITIES - _4

DEBT AND CREDIT FACILITIES - SCHEDULE OF MATURITIES OF LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2021USD ($)
Schedule Of Long Term Debt Maturities [Line Items]
2022	$ 63
2023	1,007
2024	548
2025	760
2026	1,324
Thereafter	16,397
Total	20,099
San Diego Gas and Electric Company [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2022	17
2023	450
2024	0
2025	0
2026	750
Thereafter	5,200
Total	6,417
SoCalGas
Schedule Of Long Term Debt Maturities [Line Items]
2022	0
2023	300
2024	500
2025	350
2026	500
Thereafter	3,109
Total	4,759
Other Sempra
Schedule Of Long Term Debt Maturities [Line Items]
2022	46
2023	257
2024	48
2025	410
2026	74
Thereafter	8,088
Total	$ 8,923

DEBT AND CREDIT FACILITIES - LO

DEBT AND CREDIT FACILITIES - LONG-TERM DEBT NARRATIVE (Details)	Feb. 18, 2022USD ($)	Jan. 11, 2022USD ($)	Oct. 13, 2021USD ($)	Oct. 08, 2021USD ($)	Dec. 31, 2021USD ($)	Nov. 30, 2021USD ($)	Aug. 31, 2021USD ($)	Mar. 31, 2021USD ($)lender	Dec. 31, 2020USD ($)MMBbls	Mar. 18, 2021	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Unsecured Debt					$ 9,100,000,000
Total facility					9,535,000,000
SoCalGas
Debt Instrument [Line Items]
Unsecured Debt					309,000,000
First mortgage bonds available for future issuance					1,900,000,000
Total facility					750,000,000
Gross long-term debt					4,450,000,000				$ 4,450,000,000		$ 3,800,000,000
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
First mortgage bonds available for future issuance					7,300,000,000
Total facility					1,500,000,000
Gross long-term debt					$ 6,417,000,000				$ 6,053,000,000		5,140,000,000
San Diego Gas and Electric Company [Member] | Subsequent Event | Secured Debt [Member]
Debt Instrument [Line Items]
Term of contract	2 years
Debt amount	$ 400,000,000
Proceeds from issuance of debt	200,000,000
Aggregate amount of borrowings that may be requested	$ 400,000,000
Variable percentage rate	0.625%
San Diego Gas and Electric Company [Member] | Green First Mortgage Bonds Due 2051
Debt Instrument [Line Items]
Stated percentage rate							2.95%
Debt amount							$ 750,000,000
Proceeds from issuance of debt							737,000,000
Underwriting discounts and debt issuance costs							$ 13,000,000
Sempra LNG | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity									83.40%
Sempra LNG | Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Debt Instrument [Line Items]
Term of contract									5 years
Total facility									$ 1,600,000,000
Name plate capacity (in Mtpa) | MMBbls									3.25
Initial offtake capacity (in Mtpa) | MMBbls									2.5
Stated percentage rate									2.70%
Long-term debt outstanding									$ 17,000,000
Weighted average rate					2.93%				2.82%
Sempra Energy
Debt Instrument [Line Items]
Total facility					$ 3,185,000,000
Sempra Energy | Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instrument [Line Items]
Underwriting discounts and debt issuance costs					126,000,000
Debt issuance costs (after tax)					92,000,000
Repayments of Other Debt					$ 2,350,000,000
Sempra Energy | 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instrument [Line Items]
Stated percentage rate					4.125%	4.125%
Gross long-term debt					$ 1,000,000,000				$ 0		0
Debt amount						$ 1,000,000,000
Proceeds from issuance of debt						988,000,000
Underwriting discounts and debt issuance costs						$ 12,000,000
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed						102.00%
Debt instrument, redemption price (as a percent)						100.00%
Sempra Energy | 4.125% Junior Subordinated Notes April 1, 2052(1) | US Treasury (UST) Interest Rate
Debt Instrument [Line Items]
Variable percentage rate						2.868%
Sempra Energy | 5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instrument [Line Items]
Stated percentage rate					5.75%
Gross long-term debt					$ 758,000,000				$ 758,000,000		758,000,000
Subsidiary of TOTAL SE | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity									16.60%
SI Partners
Debt Instrument [Line Items]
Term of contract						3 years
Total facility					1,000,000,000	$ 1,000,000,000
SI Partners | Senior Notes 3.25% Due 2032 | Subsequent Event
Debt Instrument [Line Items]
Stated percentage rate		3.25%
Debt amount		$ 400,000,000
Proceeds from issuance of debt		$ 390,000,000
Variable percentage rate		0.25%
Underwriting discounts and debt issuance costs		$ 10,000,000
Debt Instrument, Face Amount Issued, Percentage Of Principal		98.903%
Debt instrument, redemption price (as a percent)		101.00%
SI Partners | Senior Notes 3.25% Due 2032 | Subsequent Event | Period one
Debt Instrument [Line Items]
Debt instrument, redemption price (as a percent)		100.00%
Sempra Infrastructure
Debt Instrument [Line Items]
Gross long-term debt					$ 8,923,000,000				$ 11,247,000,000		12,298,000,000
Sempra Infrastructure | ESJ
Debt Instrument [Line Items]
Variable percentage rate								2.63%
Underwriting discounts and debt issuance costs				$ 18,000,000				$ 6,000,000
Debt Instrument, Face Amount Issued, Percentage Of Principal								90.00%
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt								$ 177,000,000
Business Combination, Debt Assumed, Number Of Lenders | lender								5
Debt Instrument, Fixed Rate								6.13%
Debt Instrument, Remaining Principal Balance, Percent								10.00%
Debt Instrument, Basis Spread On Variable Rate, Increase Every Four Years								0.25%
Write off of Deferred Debt Issuance Costs, After Tax and Noncontrolling Interest				10,000,000
Repayments of assumed debt				$ 175,000,000
Sempra Infrastructure | ESJ
Debt Instrument [Line Items]
Ownership percentage held by noncontrolling owners								50.00%	50.00%	50.00%
Sempra Infrastructure | Loan at variable rates (2.93% at December 31, 2021) December 9, 2025
Debt Instrument [Line Items]
Stated percentage rate					2.93%
Gross long-term debt					$ 341,000,000				$ 17,000,000		$ 0
Sempra Infrastructure | Variable Rate Loan Payable Maturing 2033 | Ventika
Debt Instrument [Line Items]
Write off of Deferred Debt Issuance Costs, After Tax and Noncontrolling Interest			$ 20,000,000
Repayments of debt			375,000,000
Write off of Deferred Debt Issuance Cost			$ 36,000,000

DEBT AND CREDIT FACILITIES - _5

DEBT AND CREDIT FACILITIES - SCHEDULE OF CALLABLE LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2021USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	$ 2,603
Callable long-term debt, subject to make-whole provisions	17,337
San Diego Gas and Electric Company [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	0
Callable long-term debt, subject to make-whole provisions	6,417
SoCalGas
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	304
Callable long-term debt, subject to make-whole provisions	4,450
Other Sempra
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	2,299
Callable long-term debt, subject to make-whole provisions	$ 6,470

INCOME TAXES - RECONCILIATION T

INCOME TAXES - RECONCILIATION TO EFFECTIVE TAX RATE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 99	$ 249	$ 315
Income from continuing operations before income taxes and equity earnings	219	1,489	1,734
Income (loss) from equity method investments	614	294	30
Pretax income	$ 833	$ 1,783	$ 1,764
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Outside basis differences	9.00%	0.00%	0.00%
Depreciation	8.00%	3.00%	3.00%
Non-U.S. earnings taxed at lower statutory income tax rates	5.00%	2.00%	3.00%
Foreign exchange and inflation effects	1.00%	(3.00%)	4.00%
Valuation allowances	1.00%	(1.00%)	0.00%
Tax credits	0.00%	(1.00%)	(2.00%)
Excess deferred income taxes outside of ratemaking	0.00%	0.00%	(4.00%)
Compensation-related items	(1.00%)	(1.00%)	0.00%
Impairment losses	(1.00%)	1.00%	0.00%
Noncontrolling interests	(2.00%)	0.00%	0.00%
Allowance for equity funds used during construction	(3.00%)	(1.00%)	(1.00%)
Amortization of excess deferred income taxes	(3.00%)	(1.00%)	(1.00%)
Remeasurement of deferred taxes	(4.00%)	0.00%	0.00%
State income taxes, net of federal income tax benefit	(4.00%)	1.00%	2.00%
Self-developed software expenditures	(5.00%)	(3.00%)	(2.00%)
Utility repairs expenditures	(9.00%)	(4.00%)	(3.00%)
Other, net	(1.00%)	1.00%	(2.00%)
Effective income tax rate	12.00%	14.00%	18.00%
San Diego Gas and Electric Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 201	$ 190	$ 171
Income from continuing operations before income taxes and equity earnings	1,020	1,014	945
Pretax income	$ 1,020	$ 1,014	$ 945
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Depreciation	3.00%	3.00%	3.00%
Excess deferred income taxes outside of ratemaking	0.00%	0.00%	(3.00%)
Allowance for equity funds used during construction	(2.00%)	(2.00%)	(1.00%)
Amortization of excess deferred income taxes	(2.00%)	(1.00%)	(1.00%)
State income taxes, net of federal income tax benefit	5.00%	5.00%	6.00%
Self-developed software expenditures	(1.00%)	(4.00%)	(3.00%)
Utility repairs expenditures	(4.00%)	(3.00%)	(3.00%)
Other, net	0.00%	0.00%	(1.00%)
Effective income tax rate	20.00%	19.00%	18.00%
SoCalGas
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ (310)	$ 96	$ 120
Income from continuing operations before income taxes and equity earnings	(736)	601	762
Pretax income	$ (736)	$ 601	$ 762
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Depreciation	(5.00%)	5.00%	4.00%
Excess deferred income taxes outside of ratemaking	0.00%	0.00%	(5.00%)
Allowance for equity funds used during construction	1.00%	(1.00%)	(1.00%)
Amortization of excess deferred income taxes	2.00%	(1.00%)	(1.00%)
State income taxes, net of federal income tax benefit	11.00%	2.00%	4.00%
Self-developed software expenditures	5.00%	(4.00%)	(2.00%)
Utility repairs expenditures	5.00%	(7.00%)	(4.00%)
Other, net	2.00%	(1.00%)	0.00%
Nondeductible expenditures	0.00%	2.00%	0.00%
Effective income tax rate	42.00%	16.00%	16.00%

INCOME TAXES - ADDITIONAL INFOR

INCOME TAXES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2021
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax benefit related to outside differences on plans to sell businesses		$ 89
Income tax (benefit) expense related to increase in outside basis differences	$ (7)	51
Foreign undistributed earnings			$ 1,800
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested			59
Foreign earnings repatriated	$ 4,700	254
San Diego Gas and Electric Company [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Release of regulatory liabilities		31
SoCalGas
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Release of regulatory liabilities		$ 38
Non-U.S.
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested			$ 600

INCOME TAXES - COMPONENTS OF IN

INCOME TAXES - COMPONENTS OF INCOME TAX EXPENSE (BENEFIT) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S.	$ 346	$ 1,461	$ 1,191
Non-U.S.	487	322	573
Pretax income	833	1,783	1,764
Current:
U.S. state	(6)	(22)	(14)
Non-U.S.	183	112	140
Total	177	90	126
Deferred:
U.S. federal	(9)	157	87
U.S. state	(37)	36	21
Non-U.S.	(31)	(34)	84
Total	(77)	159	192
Deferred investment tax credits	(1)	0	(3)
Total income tax expense	99	249	315
San Diego Gas and Electric Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	1,020	1,014	945
Current:
U.S. federal	35	121	35
U.S. state	13	34	31
Total	48	155	66
Deferred:
U.S. federal	99	11	75
U.S. state	54	25	32
Total	153	36	107
Deferred investment tax credits	0	(1)	(2)
Total income tax expense	201	190	171
SoCalGas
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	(736)	601	762
Current:
U.S. federal	134	163	8
U.S. state	50	45	24
Total	184	208	32
Deferred:
U.S. federal	(334)	(85)	79
U.S. state	(159)	(28)	10
Total	(493)	(113)	89
Deferred investment tax credits	(1)	1	(1)
Total income tax expense	$ (310)	$ 96	$ 120

INCOME TAXES - DEFERRED INCOME

INCOME TAXES - DEFERRED INCOME TAXES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred income tax assets:
Less: valuation allowances	$ 183	$ 174	$ 144
Deferred income taxes assets, noncurrent	151	136	155
Deferred income tax liabilities, noncurrent	3,477	2,871	2,577
Sempra
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	5,230	4,891	4,052
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	47	46	153
Regulatory balancing accounts	538	587	468
Right-of-use assets – operating leases	160	144	131
Property taxes	52	51	44
Other deferred income tax liabilities	50	40	93
Total deferred income tax liabilities	6,077	5,759	4,941
Deferred income tax assets:
Tax credits	1,135	1,161	1,136
Net operating losses	706	1,299	911
Postretirement benefits	30	162	200
Compensation-related items	164	169	161
Operating lease liabilities	140	125	131
Other deferred income tax assets	130	97	60
Bad debt allowance	33	35	4
State income taxes	21	20	8
Accrued expenses not yet deductible	575	130	52
Deferred income tax assets before valuation allowances	2,934	3,198	2,663
Less: valuation allowances	183	174	144
Total deferred income tax assets	2,751	3,024	2,519
Net deferred income tax liability	3,326	2,735	2,422
Deferred income taxes assets, noncurrent	151	136	155
Deferred income tax liabilities, noncurrent	3,477	2,871	2,577
San Diego Gas and Electric Company [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,970	1,833	1,735
Regulatory balancing accounts	323	224	141
Right-of-use assets – operating leases	52	28	32
Property taxes	35	34	30
Other deferred income tax liabilities	1	2	14
Total deferred income tax liabilities	2,381	2,121	1,952
Deferred income tax assets:
Tax credits	5	5	6
Postretirement benefits	0	14	37
Compensation-related items	12	12	6
Operating lease liabilities	52	28	32
Other deferred income tax assets	1	3	4
Bad debt allowance	16	18	3
State income taxes	4	8	7
Accrued expenses not yet deductible	16	14	9
Total deferred income tax assets	106	102	104
Net deferred income tax liability	2,275	2,019	1,848
Deferred income tax liabilities, noncurrent	2,275	2,019	1,848
SoCalGas
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,444	1,322	1,246
Regulatory balancing accounts	215	362	327
Right-of-use assets – operating leases	16	21	22
Property taxes	17	17	14
Other deferred income tax liabilities	1	1	1
Total deferred income tax liabilities	1,693	1,723	1,610
Deferred income tax assets:
Tax credits	3	3	3
Postretirement benefits	18	123	120
Compensation-related items	33	36	25
Operating lease liabilities	16	21	22
Other deferred income tax assets	18	15	13
Bad debt allowance	15	15	1
State income taxes	12	11	8
Accrued expenses not yet deductible	539	93	15
Total deferred income tax assets	654	317	207
Net deferred income tax liability	1,039	1,406	1,403
Deferred income tax liabilities, noncurrent	$ 1,039	$ 1,406	$ 1,403

INCOME TAXES - NET OPERATING LO

INCOME TAXES - NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Valuation allowances	$ 183	$ 174	$ 144
U.S. federal
Operating Loss Carryforwards [Line Items]
NOLs	3,263
Valuation allowances	128	118	90
U.S. federal | General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	436
U.S. federal | Foreign tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	688
U.S. state
Operating Loss Carryforwards [Line Items]
NOLs	2,938
Valuation allowances	31	32	33
U.S. state | General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	6
Non-U.S.
Operating Loss Carryforwards [Line Items]
NOLs	248
Valuation allowances	$ 24	$ 24	$ 21

INCOME TAXES - UNRECOGNIZED TAX

INCOME TAXES - UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits
Beginning balance	$ 99	$ 93	$ 119
Increase in prior period tax positions	3	3	5
Decrease in prior period tax positions	(2)	(1)	0
Increase in current period tax positions	204	4	2
Settlements with taxing authorities	0	0	(32)
Expiration of statutes of limitations	0	0	(1)
Ending balance	304	99	93
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(105)	(87)	(81)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	34	31	27
San Diego Gas and Electric Company [Member]
Reconciliation of Unrecognized Tax Benefits
Beginning balance	13	12	11
Increase in prior period tax positions	1	1	1
Ending balance	14	13	12
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(11)	(10)	(9)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	1	1	1
SoCalGas
Reconciliation of Unrecognized Tax Benefits
Beginning balance	68	64	61
Increase in prior period tax positions	1	1	1
Increase in current period tax positions	3	3	2
Ending balance	72	68	64
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(63)	(59)	(55)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	$ 33	$ 30	$ 26

INCOME TAXES - CHANGES IN UNREC

INCOME TAXES - CHANGES IN UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Interest and penalties expense	$ 1
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	8	$ 8	$ 8
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities | San Diego Gas and Electric Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	6	6	6
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities | SoCalGas
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ 2	$ 2	$ 2

EMPLOYEE BENEFIT PLANS - NARRAT

EMPLOYEE BENEFIT PLANS - NARRATIVE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Dedicated assets in support of certain benefit plans	$ 567	$ 512	$ 488
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	5
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	0
San Diego Gas and Electric Company [Member] | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	3
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	0
SoCalGas | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	2
SoCalGas | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	0
Oncor Electric Delivery Company LLC | Sempra Texas Utilities | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Gain (loss) arising during the period	$ 7	$ 11	$ 27

EMPLOYEE BENEFIT PLANS - EMPLOY

EMPLOYEE BENEFIT PLANS - EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (687)	$ (1,059)	$ (1,067)
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	6.75%
Pension Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 4,077	3,768	3,339
Service cost	145	129	110
Interest cost	112	129	139
Contributions from plan participants	0	0	0
Actuarial (gain) loss	(76)	351	445
Plan amendments	0	0	5
Benefit payments	(98)	(93)	(93)
Settlements	(303)	(207)	(177)
Net obligation at December 31	3,857	4,077	3,768
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	3,002	2,662	2,160
Actual return on plan assets	340	350	496
Employer contributions	241	290	276
Contributions from plan participants	0	0	0
Benefit payments	(98)	(93)	(93)
Settlements	(303)	(207)	(177)
Fair value of plan assets at December 31	3,182	3,002	2,662
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(675)	(1,075)	(1,106)
Net recorded (liability) asset at December 31	(675)	(1,075)	(1,106)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	19	0	0
Current liabilities	(19)	(35)	(59)
Noncurrent liabilities	(675)	(1,040)	(1,047)
Net recorded (liability) asset	(675)	(1,075)	(1,106)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(86)	(102)	(113)
Prior service cost	(8)	(11)	(14)
Total	(94)	(113)	(127)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	145	129	110
Interest cost	112	129	139
Expected return on assets	(173)	(169)	(144)
Amortization of prior service cost (credit)	11	12	12
Amortization of actuarial loss (gain)	45	35	36
Settlement charges	38	22	28
Net periodic benefit cost	178	158	181
Regulatory adjustment	57	91	77
Total expense recognized	235	249	258
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	(5)	28	17
Prior service cost	0	0	5
Amortization of actuarial loss	(8)	(14)	(13)
Amortization of prior service cost	(4)	(4)	(3)
Settlements	(7)	(22)	(28)
Total recognized in OCI	(24)	(12)	(22)
Total recognized in net periodic benefit cost and OCI	$ 211	$ 237	$ 236
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.04%	2.78%	3.49%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.78%	3.49%	4.29%
Expected return on plan assets	6.47%	7.00%	7.00%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 231
EXPECTED BENEFIT PAYMENTS
2022	276
2023	261
2024	253
2025	244
2026	240
2027-2031	$ 1,122
Pension Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
Pension Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Other Postretirement Benefits Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 989	$ 913	$ 868
Service cost	23	18	17
Interest cost	28	33	36
Contributions from plan participants	21	22	21
Actuarial (gain) loss	(53)	79	45
Plan amendments	0	0	0
Benefit payments	(68)	(74)	(72)
Settlements	0	(2)	(2)
Net obligation at December 31	940	989	913
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,399	1,281	1,108
Actual return on plan assets	51	164	218
Employer contributions	5	8	8
Contributions from plan participants	21	22	21
Benefit payments	(68)	(74)	(72)
Settlements	0	(2)	(2)
Fair value of plan assets at December 31	1,408	1,399	1,281
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	468	410	368
Net recorded (liability) asset at December 31	468	410	368
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	481	430	391
Current liabilities	(1)	(1)	(3)
Noncurrent liabilities	(12)	(19)	(20)
Net recorded (liability) asset	468	410	368
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	11	8	10
Prior service cost	0	0	0
Total	11	8	10
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	23	18	17
Interest cost	28	33	36
Expected return on assets	(61)	(55)	(71)
Amortization of prior service cost (credit)	(2)	(2)	0
Amortization of actuarial loss (gain)	(9)	(10)	(10)
Settlement charges	0	0	0
Net periodic benefit cost	(21)	(16)	(28)
Regulatory adjustment	21	16	29
Total expense recognized	0	0	1
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	(4)	1	(3)
Prior service cost	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Settlements	0	0	0
Total recognized in OCI	(4)	1	(3)
Total recognized in net periodic benefit cost and OCI	$ (4)	$ 1	$ (2)
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.04%	2.88%	3.54%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.88%	3.54%	4.29%
Expected return on plan assets	4.76%	4.64%	6.48%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 5
EXPECTED BENEFIT PAYMENTS
2022	46
2023	46
2024	46
2025	46
2026	48
2027-2031	$ 226
Other Postretirement Benefits Plan | Pre-65Retiree
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.00%	6.00%	6.25%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
Other Postretirement Benefits Plan | Retiree Aged 65 or Older
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	4.75%	4.75%	4.75%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
Other Postretirement Benefits Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
Other Postretirement Benefits Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
San Diego Gas and Electric Company [Member]
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (25)	$ (92)	$ (153)
San Diego Gas and Electric Company [Member] | Pension Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	913	895	814
Service cost	35	31	30
Interest cost	25	30	34
Contributions from plan participants	0	0	0
Actuarial (gain) loss	(2)	37	61
Plan amendments	0	0	3
Benefit payments	(17)	(18)	(18)
Settlements	(69)	(52)	(39)
Transfer of liability from other plans	0	(10)	10
Net obligation at December 31	885	913	895
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	819	739	600
Actual return on plan assets	73	94	135
Employer contributions	53	52	52
Contributions from plan participants	0	0	0
Benefit payments	(17)	(18)	(18)
Settlements	(69)	(52)	(39)
Transfer of assets from other plans	0	4	9
Fair value of plan assets at December 31	859	819	739
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(26)	(94)	(156)
Net recorded (liability) asset at December 31	(26)	(94)	(156)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0	0
Current liabilities	(1)	(2)	(3)
Noncurrent liabilities	(25)	(92)	(153)
Net recorded (liability) asset	(26)	(94)	(156)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(9)	(8)	(9)
Prior service cost	(1)	(2)	(7)
Total	(10)	(10)	(16)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	35	31	30
Interest cost	25	30	34
Expected return on assets	(50)	(49)	(38)
Amortization of prior service cost (credit)	1	2	3
Amortization of actuarial loss (gain)	2	3	11
Settlement charges	6	0	0
Net periodic benefit cost	19	17	40
Regulatory adjustment	34	38	14
Total expense recognized	53	55	54
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	1	6	5
Prior service cost	0	0	2
Transfer of actuarial loss (gain)	0	(7)	0
Transfer of prior service cost (credit)	0	(5)	0
Amortization of actuarial loss	0	(1)	0
Amortization of prior service cost	(1)	(1)	(1)
Total recognized in OCI	0	(8)	6
Total recognized in net periodic benefit cost and OCI	$ 53	$ 47	$ 60
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.99%	2.73%	3.44%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.73%	3.44%	4.29%
Expected return on plan assets	6.25%	7.00%	7.00%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 52
EXPECTED BENEFIT PAYMENTS
2022	71
2023	69
2024	66
2025	65
2026	59
2027-2031	$ 275
San Diego Gas and Electric Company [Member] | Pension Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	3.50%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
San Diego Gas and Electric Company [Member] | Pension Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 193	$ 177	$ 170
Service cost	5	4	4
Interest cost	5	6	7
Contributions from plan participants	7	8	7
Actuarial (gain) loss	(3)	17	7
Plan amendments	0	0	0
Benefit payments	(19)	(20)	(18)
Settlements	0	0	0
Transfer of liability from other plans	0	1	0
Net obligation at December 31	188	193	177
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	213	197	172
Actual return on plan assets	(5)	26	36
Employer contributions	1	1	0
Contributions from plan participants	7	8	7
Benefit payments	(19)	(20)	(18)
Settlements	0	0	0
Transfer of assets from other plans	0	1	0
Fair value of plan assets at December 31	197	213	197
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	9	20	20
Net recorded (liability) asset at December 31	9	20	20
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	9	20	20
Current liabilities	0	0	0
Noncurrent liabilities	0	0	0
Net recorded (liability) asset	9	20	20
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	5	4	4
Interest cost	5	6	7
Expected return on assets	(10)	(10)	(11)
Amortization of prior service cost (credit)	0	0	2
Amortization of actuarial loss (gain)	(2)	(3)	(2)
Settlement charges	0	0	0
Net periodic benefit cost	(2)	(3)	0
Regulatory adjustment	2	3	0
Total expense recognized	0	0	0
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	0	0	0
Prior service cost	0	0	0
Transfer of actuarial loss (gain)	0	0	0
Transfer of prior service cost (credit)	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Total recognized in OCI	0	0	0
Total recognized in net periodic benefit cost and OCI	$ 0	$ 0	$ 0
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.05%	2.85%	3.55%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.85%	3.55%	4.30%
Expected return on plan assets	4.81%	5.51%	6.92%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2022	9
2023	10
2024	10
2025	10
2026	10
2027-2031	$ 48
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Pre-65Retiree
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.00%	6.00%	6.25%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Retiree Aged 65 or Older
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	4.75%	4.75%	4.75%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	3.50%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
SoCalGas | Pension Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 2,829	$ 2,526	$ 2,148
Service cost	97	86	68
Interest cost	78	88	91
Contributions from plan participants	0	0	0
Actuarial (gain) loss	(83)	282	345
Plan amendments	0	0	2
Benefit payments	(63)	(60)	(59)
Settlements	(211)	(105)	(65)
Transfer of liability from other plans	0	12	(4)
Net obligation at December 31	2,647	2,829	2,526
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,969	1,737	1,385
Actual return on plan assets	243	243	320
Employer contributions	157	152	152
Contributions from plan participants	0	0	0
Benefit payments	(63)	(60)	(59)
Settlements	(211)	(105)	(65)
Transfer of assets from other plans	0	2	4
Fair value of plan assets at December 31	2,095	1,969	1,737
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(552)	(860)	(789)
Net recorded (liability) asset at December 31	(552)	(860)	(789)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0	0
Current liabilities	(1)	(7)	(4)
Noncurrent liabilities	(551)	(853)	(785)
Net recorded (liability) asset	(552)	(860)	(789)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(15)	(14)	(7)
Prior service cost	(3)	(4)	(3)
Total	(18)	(18)	(10)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	97	86	68
Interest cost	78	88	91
Expected return on assets	(113)	(107)	(94)
Amortization of prior service cost (credit)	8	8	8
Amortization of actuarial loss (gain)	36	26	16
Settlement charges	25	0	0
Net periodic benefit cost	131	101	89
Regulatory adjustment	23	53	63
Total expense recognized	154	154	152
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	2	6	2
Prior service cost	0	0	3
Transfer of actuarial loss (gain)	0	5	(4)
Transfer of prior service cost (credit)	0	3	(1)
Amortization of actuarial loss	(1)	(1)	(1)
Amortization of prior service cost	(1)	(1)	0
Total recognized in OCI	0	12	(1)
Total recognized in net periodic benefit cost and OCI	$ 154	$ 166	$ 151
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.04%	2.79%	3.50%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.79%	3.50%	4.30%
Expected return on plan assets	6.75%	7.00%	7.00%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 152
EXPECTED BENEFIT PAYMENTS
2022	171
2023	163
2024	158
2025	156
2026	153
2027-2031	$ 725
SoCalGas | Pension Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
SoCalGas | Pension Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
SoCalGas | Other Postretirement Benefits Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 749	$ 688	$ 646
Service cost	17	14	12
Interest cost	22	25	27
Contributions from plan participants	13	14	13
Actuarial (gain) loss	(49)	57	39
Plan amendments	0	0	0
Benefit payments	(46)	(49)	(49)
Settlements	0	0	0
Transfer of liability from other plans	0	0	0
Net obligation at December 31	706	749	688
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,159	1,059	916
Actual return on plan assets	51	134	178
Employer contributions	1	1	1
Contributions from plan participants	13	14	13
Benefit payments	(46)	(49)	(49)
Settlements	0	0	0
Transfer of assets from other plans	0	0	0
Fair value of plan assets at December 31	1,178	1,159	1,059
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	472	410	371
Net recorded (liability) asset at December 31	472	410	371
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	472	410	371
Current liabilities	0	0	0
Noncurrent liabilities	0	0	0
Net recorded (liability) asset	472	410	371
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	17	14	12
Interest cost	22	25	27
Expected return on assets	(48)	(43)	(58)
Amortization of prior service cost (credit)	(3)	(2)	(2)
Amortization of actuarial loss (gain)	(7)	(7)	(8)
Settlement charges	0	0	0
Net periodic benefit cost	(19)	(13)	(29)
Regulatory adjustment	19	13	29
Total expense recognized	0	0	0
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	0	0	0
Prior service cost	0	0	0
Transfer of actuarial loss (gain)	0	0	0
Transfer of prior service cost (credit)	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Total recognized in OCI	0	0	0
Total recognized in net periodic benefit cost and OCI	$ 0	$ 0	$ 0
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.05%	2.90%	3.55%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.90%	3.55%	4.30%
Expected return on plan assets	4.70%	4.41%	6.38%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2022	33
2023	33
2024	33
2025	33
2026	33
2027-2031	$ 166
SoCalGas | Other Postretirement Benefits Plan | Pre-65Retiree
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.00%	6.00%	6.25%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
SoCalGas | Other Postretirement Benefits Plan | Retiree Aged 65 or Older
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	4.75%	4.75%	4.75%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
SoCalGas | Other Postretirement Benefits Plan | Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
SoCalGas | Other Postretirement Benefits Plan | Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Funded Plan | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	$ 2,612	$ 3,679	$ 3,578
Accumulated benefit obligation	2,277	3,265	3,229
Fair value of plan assets	2,095	2,788	2,662
Funded Plan | Other Postretirement Benefits Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	34	33	32
Fair value of plan assets	33	27	25
Funded Plan | San Diego Gas and Electric Company [Member] | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation		887	861
Accumulated benefit obligation		834	818
Fair value of plan assets		819	739
Funded Plan | SoCalGas | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	2,612	2,792	2,505
Accumulated benefit obligation	2,277	2,431	2,208
Fair value of plan assets	2,095	1,969	1,737
Unfunded Plan | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	178	184	190
Accumulated benefit obligation	139	146	158
Unfunded Plan | Other Postretirement Benefits Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	12	14	16
Unfunded Plan | San Diego Gas and Electric Company [Member] | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	26	26	34
Accumulated benefit obligation	22	22	27
Unfunded Plan | SoCalGas | Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	35	37	21
Accumulated benefit obligation	$ 29	$ 31	$ 17

EMPLOYEE BENEFIT PLANS - PLAN A

EMPLOYEE BENEFIT PLANS - PLAN ASSETS (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.47%	7.00%	7.00%
Domestic Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	31.00%
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	21.00%
Long Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	21.00%
Diversified Real Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	10.00%
Return Seeking Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	10.00%
Ultra-long duration government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	5.00%
Other Diversifying Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	2.00%
Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	74.00%
Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	26.00%
Minimum | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
Minimum | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	1.00%
Maximum | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	12.00%
Maximum | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
San Diego Gas and Electric Company [Member] | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.25%	7.00%	7.00%
San Diego Gas and Electric Company [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	38.00%
San Diego Gas and Electric Company [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	62.00%
SoCalGas | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%	7.00%	7.00%
SoCalGas | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	30.00%
Asset allocations	38.00%
SoCalGas | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	70.00%
Asset allocations	62.00%

EMPLOYEE BENEFIT PLANS - FAIR V

EMPLOYEE BENEFIT PLANS - FAIR VALUE OF PLAN ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%
Return Seeking Assets [Member] | Maximum
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	12.00%
Risk Mitigating Assets [Member] | Maximum
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 3,182	$ 3,002	$ 2,662	$ 2,160
Expected return on plan assets	6.47%	7.00%	7.00%
Pension Plan | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 18	$ 7	$ 17
Pension Plan | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	849	931	923
Pension Plan | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	385	563	556
Pension Plan | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	225	188	95
Pension Plan | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	33	32	3
Pension Plan | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	487	272	267
Pension Plan | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	11	13	9
Pension Plan | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	413	418	346
Pension Plan | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	65	61	62
Pension Plan | Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
Pension Plan | Accounts receivable/payable, net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(20)	13	(38)
Pension Plan | Investments measured at NAV:
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	657	493	417
Pension Plan | Venture capital funds and real estate funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	58	10	5
Pension Plan | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2,487	2,486	2,278
Pension Plan | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,947	1,924	1,819
Pension Plan | Level 1 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18	7	17
Pension Plan | Level 1 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	844	931	923
Pension Plan | Level 1 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	384	563	555
Pension Plan | Level 1 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	204	151	93
Pension Plan | Level 1 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	33	32	3
Pension Plan | Level 1 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	463	238	228
Pension Plan | Level 1 | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Pension Plan | Level 1 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Pension Plan | Level 1 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Pension Plan | Level 1 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	2
Pension Plan | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	540	562	459
Pension Plan | Level 2 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Pension Plan | Level 2 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	0	0
Pension Plan | Level 2 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0	1
Pension Plan | Level 2 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	37	2
Pension Plan | Level 2 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Pension Plan | Level 2 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	24	34	39
Pension Plan | Level 2 | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	11	13	9
Pension Plan | Level 2 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	413	418	346
Pension Plan | Level 2 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	65	61	62
Pension Plan | Level 2 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	(1)
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1,408	$ 1,399	$ 1,281	1,108
Expected return on plan assets	4.76%	4.64%	6.48%
Other Postretirement Benefits Plan | Level 1 | Total Sempra investment assets in the fair value hierarchy
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 598	$ 624	$ 602
Other Postretirement Benefits Plan | Level 2 | Total Sempra investment assets in the fair value hierarchy
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	505	533	478
San Diego Gas and Electric Company [Member] | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 859	$ 819	$ 739	600
Expected return on plan assets	6.25%	7.00%	7.00%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 197	$ 213	$ 197	172
Expected return on plan assets	4.81%	5.51%	6.92%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 16	$ 17	$ 21
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	11	13
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	83	76	65
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	11	11
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	25	40	33
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	8	8
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1	1
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Accounts receivable/payable, net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(1)	(2)	(2)
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Investments measured at NAV:
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	49	51	47
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	149	164	152
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	138	146	134
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	16	17	21
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	11	13
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	82	69	57
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	11	11
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	24	38	32
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 1 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	11	18	18
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	7	8
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	2	1
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	8	8
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan | Level 2 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1	1
SoCalGas | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 2,095	$ 1,969	$ 1,737	1,385
Expected return on plan assets	6.75%	7.00%	7.00%
SoCalGas | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1,178	$ 1,159	$ 1,059	$ 916
Expected return on plan assets	4.70%	4.41%	6.38%
SoCalGas | Other Postretirement Benefits Plan | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 2	$ 1	$ 3
SoCalGas | Other Postretirement Benefits Plan | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	84	76	78
SoCalGas | Other Postretirement Benefits Plan | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	37	46	48
SoCalGas | Other Postretirement Benefits Plan | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	147	139	127
SoCalGas | Other Postretirement Benefits Plan | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	3
SoCalGas | Other Postretirement Benefits Plan | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	258	298	288
SoCalGas | Other Postretirement Benefits Plan | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	12	15	11
SoCalGas | Other Postretirement Benefits Plan | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	337	349	309
SoCalGas | Other Postretirement Benefits Plan | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	49	42	40
SoCalGas | Other Postretirement Benefits Plan | Derivative financial instruments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1	3
SoCalGas | Other Postretirement Benefits Plan | Accounts receivable/payable, net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(1)		(5)
SoCalGas | Other Postretirement Benefits Plan | Investments measured at NAV:
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	244	188	157
SoCalGas | Other Postretirement Benefits Plan | Venture capital funds and real estate funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	1
SoCalGas | Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	929	970	907
SoCalGas | Other Postretirement Benefits Plan | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	441	459	452
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	1	3
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	83	76	78
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	37	46	48
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	74	58	52
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	3
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	241	273	267
SoCalGas | Other Postretirement Benefits Plan | Level 1 | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1	1
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 1 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 1 | Derivative financial instruments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1	3
SoCalGas | Other Postretirement Benefits Plan | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	488	511	455
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	73	81	75
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Registered Investment Company International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	17	25	21
SoCalGas | Other Postretirement Benefits Plan | Level 2 | International government bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	11	14	10
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	337	349	309
SoCalGas | Other Postretirement Benefits Plan | Level 2 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	49	42	40
SoCalGas | Other Postretirement Benefits Plan | Level 2 | Derivative financial instruments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0	0
Other Sempra | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	33	27	25
Other Sempra | Other Postretirement Benefits Plan | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	10	9
Other Sempra | Other Postretirement Benefits Plan | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	6	4
Other Sempra | Other Postretirement Benefits Plan | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	0
Other Sempra | Other Postretirement Benefits Plan | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2	4
Other Sempra | Other Postretirement Benefits Plan | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4	3
Other Sempra | Other Postretirement Benefits Plan | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1	1
Other Sempra | Other Postretirement Benefits Plan | Investments measured at NAV:
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	4	4
Other Sempra | Other Postretirement Benefits Plan | Venture capital funds and real estate funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Other Sempra | Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	25	23	21
Other Sempra | Other Postretirement Benefits Plan | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19	19	16
Other Sempra | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	10	9
Other Sempra | Other Postretirement Benefits Plan | Level 1 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	6	4
Other Sempra | Other Postretirement Benefits Plan | Level 1 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	1
Other Sempra | Other Postretirement Benefits Plan | Level 1 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	2	3
Other Sempra | Other Postretirement Benefits Plan | Level 1 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Other Sempra | Other Postretirement Benefits Plan | Level 1 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Other Sempra | Other Postretirement Benefits Plan | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	4	5
Other Sempra | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Other Sempra | Other Postretirement Benefits Plan | Level 2 | Equity Securities, International
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0	0
Other Sempra | Other Postretirement Benefits Plan | Level 2 | Equity Securities, Registered Investment Company Domestic
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	(1)
Other Sempra | Other Postretirement Benefits Plan | Level 2 | Domestic government and government agencies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0	1
Other Sempra | Other Postretirement Benefits Plan | Level 2 | Domestic corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4	3
Other Sempra | Other Postretirement Benefits Plan | Level 2 | International corporate bonds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1	$ 1	$ 1

EMPLOYEE BENEFIT PLANS - SAVING

EMPLOYEE BENEFIT PLANS - SAVINGS PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 52	$ 47	$ 44
Market value of employer stock held by plan	1,000	1,100	1,300
San Diego Gas and Electric Company [Member]
Savings Plan [Line Items]
Employer contributions to defined benefit plan	18	16	15
SoCalGas
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 28	$ 25	$ 24

SHARE-BASED COMPENSATION - SHAR

SHARE-BASED COMPENSATION - SHARE-BASED COMPENSATION EXPENSE/ OPTIONS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Number of shares available for future grants (in shares)	5,986,241
Number of shares authorized for issuance (in shares)	5,986,241
Share-based compensation expense, before income taxes	$ 58	$ 62	$ 66
Income tax benefit	(16)	(17)	(18)
Share-based Payment Arrangement, Expense, after Tax	42	45	48
Capitalized share-based compensation cost	9	11	11
Excess income tax (benefit) deficiency	$ (9)	$ (19)	$ 4
Stock option exercise period (in years)	3 years
Weighted-average fair value for options granted (in dollars per share)	$ 19.07	$ 19.76	$ 13.20
Stock price volatility (as a percent)	26.57%	18.78%	18.63%
Expected term (in years)	5 years 4 months 9 days	5 years 4 months 2 days	5 years 4 months 2 days
Risk-free rate of return (as a percent)	0.41%	1.68%	2.49%
Annual dividend yield (as a percent)	3.38%	2.60%	3.35%
Common shares under options
Beginning balance (in shares)	365,395
Options grants in period (in shares)	222,620	154,860	261,075
Exercised (in shares)	(50,671)	(4,400)	(52,540)
Ending balance (in shares)	537,344	365,395
Vested at period end (in shares)	537,344
Exercisable at period end (in shares)	152,189
Weighted- average exercise price
Beginning balance (in dollars per share)	$ 120.93
Granted (in dollars per share)	123.80
Exercised (in dollars per share)	106.76
Ending balance (in dollars per share)	123.45	$ 120.93
Vested at period end, Weighted- average exercise price (in dollars per share)	123.45
Exercisable at period end, Weighted- average exercise price (in dollars per share)	$ 118.10
Outstanding at period end, Weighted- average remaining contractual term	8 years 21 days
Vested at period end, Weighted- average remaining contractual term	8 years 21 days
Exercisable at period end, Weighted- average remaining contractual term	7 years 3 months 7 days
Outstanding at period end, Aggregate intrinsic value	$ 5
Vested at period end, Aggregate intrinsic value	5
Exercisable at period end, Aggregate intrinsic value	2
Aggregate intrinsic value of options exercised	$ 1.4	$ 0.4	$ 4
Weighted average period over which unrecognized compensation cost will be recognized	1 year 1 month 6 days
Weighted-average per share fair value for nonqualified stock options granted (in dollars per share)		$ 149.12	$ 106.76
Cash received from exercise of options	$ 5		$ 3
San Diego Gas and Electric Company [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	10	$ 11	10
Income tax benefit	(3)	(3)	(3)
Share-based Payment Arrangement, Expense, after Tax	7	8	7
Capitalized share-based compensation cost	5	7	6
Excess income tax (benefit) deficiency	(1)	(3)	1
SoCalGas
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	14	14	15
Income tax benefit	(4)	(4)	(4)
Share-based Payment Arrangement, Expense, after Tax	10	10	11
Capitalized share-based compensation cost	4	4	5
Excess income tax (benefit) deficiency	$ (1)	$ (3)	$ 1
Share-based Payment Arrangement, Option
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Expiration period	10 years
Awards Granted In 2020 and 2019 | Share-based Payment Arrangement, Option
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awarded during or after 2015 | Performance Shares
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Award vesting rights maximum additional award	100.00%
Award vesting rights, Increase modifier for top quartile	20.00%
Award vesting rights, decrease modifier for bottom quartile	20.00%
Awards Granted Prior to 2015 | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	4 years
Awarded During Or After 2014
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting rights maximum additional award	100.00%
Awards Granted in 2019 | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awards Granted During 2015 Through 2018 | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Minimum | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Maximum | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	4 years

SHARE-BASED COMPENSATION - RSAs

SHARE-BASED COMPENSATION - RSAs AND RSUs (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free rate of return (as a percent)	0.41%	1.68%	2.49%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Maximum Performance Based RSU Target Performance Conditions Exceeded For Awards Granted during or after 2014	100.00%
Weighted average period over which unrecognized compensation cost will be recognized	1 year 1 month 6 days
Share-Based Compensation, Restricted Stock Awards And Units
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Stock price volatility (as a percent)	33.39%	16.35%	17.74%
Risk-free rate of return (as a percent)	0.16%	1.55%	2.46%
Performance-based restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	893,961
Granted (in shares)	323,889
Vested (in shares)	(317,128)
Forfeited (in shares)	(29,945)
Nonvested, end of period (in shares)	870,777	893,961
Expected to vest (in shares)	854,697
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 121.61
Weighted average grant date fair value, granted (in dollars per share)	133.03	$ 155.62	$ 113.54
Weighted average grant date fair value, vested (in dollars per share)	105.03
Weighted average grant date fair value, forfeited (in dollars per share)	131.55
Weighted average grant date fair value, end of period (in dollars per share)	131.64	$ 121.61
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 131.47
Service-based restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	343,577
Granted (in shares)	143,980
Vested (in shares)	(202,352)
Forfeited (in shares)	(7,905)
Nonvested, end of period (in shares)	277,300	343,577
Expected to vest (in shares)	271,197
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 121.59
Weighted average grant date fair value, granted (in dollars per share)	124.84	$ 138.91	$ 112.50
Weighted average grant date fair value, vested (in dollars per share)	116.28
Weighted average grant date fair value, forfeited (in dollars per share)	161.49
Weighted average grant date fair value, end of period (in dollars per share)	127.54	$ 121.59
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 127.47
Share-Based Compensation, Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity instruments other than options, vested in the period, fair value	$ 57	$ 70	$ 36
Nonvested awards, compensation cost not yet recognized	$ 17
Weighted average period over which unrecognized compensation cost will be recognized	1 year 6 months

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - COMMODITY VOLUMES (Details)	12 Months Ended
	Dec. 31, 2021MWhMMBTU	Dec. 31, 2020MWhMMBTU	Dec. 31, 2019MMBTUMWh
Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	184	189	231
Electricity
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	1	2
Congestion revenue rights
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	45	43	48
SDG&E | Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	7	16	37
SDG&E | Electricity
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	1	2
SDG&E | Congestion revenue rights
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	45	43	48
SoCalGas | Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	201	185	201

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - NOTIONALS AMOUNTS (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cross-currency swaps
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 306,000,000	$ 306,000,000	$ 306,000,000
Other foreign currency derivatives
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	106,000,000	1,764,000,000	1,796,000,000
Cash flow hedges | Interest rate instruments
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 462,000,000	$ 1,486,000,000	$ 1,445,000,000

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - BALANCE SHEET (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	$ 74,000,000	$ 57,000,000
Additional margin posted for commodity contracts not subject to rate recovery	58,000,000	21,000,000
Additional margin posted for commodity contracts subject to rate recovery	46,000,000	30,000,000
Total	178,000,000	108,000,000
Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	62,000,000	100,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	62,000,000	100,000,000
Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(87,000,000)	(72,000,000)
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(87,000,000)	(72,000,000)
Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(134,000,000)	(188,000,000)
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(134,000,000)	(188,000,000)
Derivatives designated as hedging instruments: | Other current assets
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	0	0	$ 0
Foreign exchange instruments	1,000,000	0	0
Interest rate and foreign exchange instruments	0	0	0
Derivatives designated as hedging instruments: | Other long-term assets
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	6,000,000	1,000,000	3,000,000
Foreign exchange instruments	1,000,000	0	0
Interest rate and foreign exchange instruments	0	0	0
Derivatives designated as hedging instruments: | Other current liabilities
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	(6,000,000)	(16,000,000)	(11,000,000)
Foreign exchange instruments	(1,000,000)	(9,000,000)	(6,000,000)
Interest rate and foreign exchange instruments	(1,000,000)	(1,000,000)	0
Derivatives designated as hedging instruments: | Deferred credits and other
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	(2,000,000)	(31,000,000)	(17,000,000)
Foreign exchange instruments	0	(2,000,000)	(1,000,000)
Interest rate and foreign exchange instruments	(130,000,000)	(127,000,000)	(122,000,000)
Derivatives not designated as hedging instruments: | Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments		24,000,000	41,000,000
Associated offsetting foreign exchange instruments			(20,000,000)
Commodity contracts not subject to rate recovery	136,000,000	82,000,000	34,000,000
Associated offsetting commodity contracts not subject to rate recovery	(93,000,000)	(82,000,000)	(32,000,000)
Commodity contracts subject to rate recovery	38,000,000	35,000,000	41,000,000
Associated offsetting commodity contracts subject to rate recovery	(8,000,000)	(2,000,000)	(6,000,000)
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			58,000,000
Additional margin posted for commodity contracts not subject to rate recovery			43,000,000
Additional margin posted for commodity contracts subject to rate recovery			25,000,000
Total			126,000,000
Derivatives not designated as hedging instruments: | Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments		0	0
Associated offsetting foreign exchange instruments			0
Commodity contracts not subject to rate recovery	11,000,000	17,000,000	11,000,000
Associated offsetting commodity contracts not subject to rate recovery	(8,000,000)	(13,000,000)	(2,000,000)
Commodity contracts subject to rate recovery	52,000,000	95,000,000	76,000,000
Associated offsetting commodity contracts subject to rate recovery	0	0	(3,000,000)
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			85,000,000
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			85,000,000
Derivatives not designated as hedging instruments: | Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments		0	(20,000,000)
Associated offsetting foreign exchange instruments			20,000,000
Commodity contracts not subject to rate recovery	(122,000,000)	(95,000,000)	(41,000,000)
Associated offsetting commodity contracts not subject to rate recovery	93,000,000	82,000,000	32,000,000
Commodity contracts subject to rate recovery	(58,000,000)	(35,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	8,000,000	2,000,000	6,000,000
Associated cash collateral commodity contracts subject to rate recovery			14,000,000
Net amount presented on balance sheet			(53,000,000)
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(53,000,000)
Derivatives not designated as hedging instruments: | Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments		0	0
Associated offsetting foreign exchange instruments			0
Commodity contracts not subject to rate recovery	(10,000,000)	(16,000,000)	(10,000,000)
Associated offsetting commodity contracts not subject to rate recovery	8,000,000	13,000,000	2,000,000
Commodity contracts subject to rate recovery	0	(25,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	0	0	3,000,000
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			(192,000,000)
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(192,000,000)
San Diego Gas and Electric Company [Member] | Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	29,000,000	31,000,000
Additional margin posted for commodity contracts subject to rate recovery	28,000,000	24,000,000
Total	57,000,000	55,000,000
San Diego Gas and Electric Company [Member] | Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	52,000,000	95,000,000
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	52,000,000	95,000,000
San Diego Gas and Electric Company [Member] | Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(15,000,000)	(27,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(15,000,000)	(27,000,000)
San Diego Gas and Electric Company [Member] | Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	0	(25,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	(25,000,000)
San Diego Gas and Electric Company [Member] | Derivatives not designated as hedging instruments: | Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	34,000,000	32,000,000	30,000,000
Associated offsetting commodity contracts subject to rate recovery	(5,000,000)	(1,000,000)	(4,000,000)
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			26,000,000
Additional margin posted for commodity contracts subject to rate recovery			16,000,000
Total			42,000,000
San Diego Gas and Electric Company [Member] | Derivatives not designated as hedging instruments: | Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	52,000,000	95,000,000	76,000,000
Associated offsetting commodity contracts subject to rate recovery	0	0	(3,000,000)
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			73,000,000
Additional margin posted for commodity contracts subject to rate recovery			0
Total			73,000,000
San Diego Gas and Electric Company [Member] | Derivatives not designated as hedging instruments: | Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	(20,000,000)	(28,000,000)	(41,000,000)
Associated offsetting commodity contracts subject to rate recovery	5,000,000	1,000,000	4,000,000
Associated cash collateral commodity contracts subject to rate recovery			14,000,000
Net amount presented on balance sheet			(23,000,000)
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(23,000,000)
San Diego Gas and Electric Company [Member] | Derivatives not designated as hedging instruments: | Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	0	(25,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	0	0	3,000,000
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			(44,000,000)
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(44,000,000)
SoCalGas | Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	1,000,000	2,000,000
Additional margin posted for commodity contracts subject to rate recovery	18,000,000	6,000,000
Total	19,000,000	8,000,000
SoCalGas | Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	0
SoCalGas | Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(35,000,000)	(6,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(35,000,000)	(6,000,000)
SoCalGas | Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	0
SoCalGas | Derivatives not designated as hedging instruments: | Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	4,000,000	3,000,000	11,000,000
Associated offsetting commodity contracts subject to rate recovery	(3,000,000)	(1,000,000)	(2,000,000)
Net amount presented on balance sheet			9,000,000
Additional margin posted for commodity contracts subject to rate recovery			9,000,000
Total			18,000,000
SoCalGas | Derivatives not designated as hedging instruments: | Other long-term assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	0	0	0
Associated offsetting commodity contracts subject to rate recovery	0	0	0
Net amount presented on balance sheet			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			0
SoCalGas | Derivatives not designated as hedging instruments: | Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	(38,000,000)	(7,000,000)	(6,000,000)
Associated offsetting commodity contracts subject to rate recovery	3,000,000	1,000,000	2,000,000
Net amount presented on balance sheet			(4,000,000)
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(4,000,000)
SoCalGas | Derivatives not designated as hedging instruments: | Deferred credits and other
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	0	0	0
Associated offsetting commodity contracts subject to rate recovery	$ 0	$ 0	0
Net amount presented on balance sheet			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			$ 0

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - INCOME STATEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivatives designated as hedging instruments: | Cash flow hedges
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	$ 115	$ (232)	$ (187)
Pretax (loss) gain reclassified from AOCI into earnings	(92)	(67)	(11)
Derivatives designated as hedging instruments: | Cash flow hedges | Gain (Loss) on Sale of Assets | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(10)
Derivatives designated as hedging instruments: | Cash flow hedges | Interest Expense | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	29	(34)	(24)
Pretax (loss) gain reclassified from AOCI into earnings	(11)	(10)	(3)
Derivatives designated as hedging instruments: | Cash flow hedges | Interest Expense | Interest rate and foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	(4)	(6)	19
Pretax (loss) gain reclassified from AOCI into earnings	(1)	(1)	0
Derivatives designated as hedging instruments: | Cash flow hedges | Equity Earnings | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	71	(185)	(164)
Pretax (loss) gain reclassified from AOCI into earnings	(73)	(46)	(3)
Derivatives designated as hedging instruments: | Cash flow hedges | Equity Earnings | Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	8	(3)	(10)
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(2)
Derivatives designated as hedging instruments: | Cash flow hedges | Revenues: Energy- Related Businesses | Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	11	(4)	(8)
Pretax (loss) gain reclassified from AOCI into earnings	(1)	1	(2)
Derivatives designated as hedging instruments: | Cash flow hedges | Other Income (Expense), Net | Interest rate and foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain reclassified from AOCI into earnings	(6)	(11)	9
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(219)	42	(100)
Derivatives not designated as hedging instruments: | Revenues: Energy- Related Businesses | Commodity contracts not subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(203)	17	12
Derivatives not designated as hedging instruments: | Other Income (Expense), Net | Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(22)	(56)	25
Derivatives not designated as hedging instruments: | Cost of Natural Gas | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(25)	(7)	3
Derivatives not designated as hedging instruments: | Cost of Electric Fuel and Purchased Power | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	31	88	(140)
San Diego Gas and Electric Company [Member] | Derivatives designated as hedging instruments: | Cash flow hedges | Interest Expense | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	(1)
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(3)
San Diego Gas and Electric Company [Member] | Derivatives not designated as hedging instruments: | Cost of Electric Fuel and Purchased Power | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	31	88	(140)
SoCalGas | Derivatives designated as hedging instruments: | Cash flow hedges | Interest Expense | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(1)
SoCalGas | Derivatives not designated as hedging instruments: | Cost of Natural Gas | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	$ (25)	$ (7)	$ 3

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES ADDITIONAL INFORMATION (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (47)
Maximum length of time hedged in cash flow hedge	13 years
Cash flow hedge gain (loss) to be reclassified within 12 months, attributable to noncontrolling interest	$ (1)
Equity Method Investee
Derivative Instruments, Gain (Loss) [Line Items]
Maximum length of time hedged in cash flow hedge	18 years
SoCalGas
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (1)

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	$ 88	$ 16	$ 21
Aggregate fair value of additional collateral	88
SoCalGas
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	36	$ 6	$ 4
Aggregate fair value of additional collateral	$ 36

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Alternative investment			$ 5
Fair Value, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 1,004	$ 1,028	1,090
Short-term investments held in Rabbi Trust	81	61	66
Support Agreement, net of related guarantee fees	7	7
Assets fair value disclosure, total	1,332	1,304	1,367
Effect of netting and allocation of collateral			(14)
Support Agreement, net of related guarantee fees		4
Liabilities fair value disclosure, total	221	264	245
Fair Value, Recurring | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	3	3	16
Fair Value, Recurring | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	364	364	509
Fair Value, Recurring | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	56	65	57
Fair Value, Recurring | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
Fair Value, Recurring | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
Fair Value, Recurring | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	637	661	565
Fair Value, Recurring | Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	6	1	3
Derivative liability	8	47	28
Fair Value, Recurring | Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	2	24	21
Derivative liability	1	11	7
Fair Value, Recurring | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	46	4	11
Effect of netting and allocation of collateral	58	21	43
Derivative liability	31	16	17
Fair Value, Recurring | Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	131	128	122
Fair Value, Recurring | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	82	128	108
Effect of netting and allocation of collateral	46	30	25
Derivative liability	50	58	85
Fair Value, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	419	408	563
Short-term investments held in Rabbi Trust	81	61	66
Support Agreement, net of related guarantee fees	0	0
Assets fair value disclosure, total	601	515	688
Effect of netting and allocation of collateral			(14)
Support Agreement, net of related guarantee fees		0
Liabilities fair value disclosure, total	0	0	0
Fair Value, Recurring | Level 1 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	13	9	14
Fair Value, Recurring | Level 1 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	358	358	503
Fair Value, Recurring | Level 1 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
Fair Value, Recurring | Level 1 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 1 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 1 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
Fair Value, Recurring | Level 1 | Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring | Level 1 | Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring | Level 1 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Effect of netting and allocation of collateral	58	21	43
Derivative liability	0	0	0
Fair Value, Recurring | Level 1 | Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	0	0	0
Fair Value, Recurring | Level 1 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	12	6	5
Effect of netting and allocation of collateral	31	19	11
Derivative liability	0	0	14
Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	585	620	527
Short-term investments held in Rabbi Trust	0	0	0
Support Agreement, net of related guarantee fees	0	0
Assets fair value disclosure, total	649	655	578
Effect of netting and allocation of collateral			0
Support Agreement, net of related guarantee fees		0
Liabilities fair value disclosure, total	206	208	178
Fair Value, Recurring | Level 2 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	(10)	(6)	2
Fair Value, Recurring | Level 2 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	6	6	6
Fair Value, Recurring | Level 2 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	8	24	11
Fair Value, Recurring | Level 2 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
Fair Value, Recurring | Level 2 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
Fair Value, Recurring | Level 2 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	589	620	519
Fair Value, Recurring | Level 2 | Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	6	1	3
Derivative liability	8	47	28
Fair Value, Recurring | Level 2 | Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	2	24	21
Derivative liability	1	11	7
Fair Value, Recurring | Level 2 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	46	4	11
Effect of netting and allocation of collateral	0	0	0
Derivative liability	31	16	17
Fair Value, Recurring | Level 2 | Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	131	128	122
Fair Value, Recurring | Level 2 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	1	1	8
Effect of netting and allocation of collateral	9	5	8
Derivative liability	35	6	4
Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Short-term investments held in Rabbi Trust	0	0	0
Support Agreement, net of related guarantee fees	7	7
Assets fair value disclosure, total	82	134	101
Effect of netting and allocation of collateral			0
Support Agreement, net of related guarantee fees		4
Liabilities fair value disclosure, total	15	56	67
Fair Value, Recurring | Level 3 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring | Level 3 | Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring | Level 3 | Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring | Level 3 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Effect of netting and allocation of collateral	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring | Level 3 | Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	0	0	0
Fair Value, Recurring | Level 3 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	69	121	95
Effect of netting and allocation of collateral	6	6	6
Derivative liability	15	52	67
San Diego Gas and Electric Company [Member] | Fair Value, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	1,004	1,028	1,090
Assets fair value disclosure, total	1,113	1,178	1,205
Liabilities fair value disclosure, total	15	52	67
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	3	3	16
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	364	364	509
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	56	65	57
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	637	661	565
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	81	126	99
Effect of netting and allocation of collateral	28	24	16
Derivative liability	15	52	81
Effect of netting and allocation of collateral			(14)
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	419	408	563
Assets fair value disclosure, total	453	431	574
Liabilities fair value disclosure, total	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	13	9	14
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	358	358	503
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 1 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	12	5	1
Effect of netting and allocation of collateral	22	18	10
Derivative liability	0	0	14
Effect of netting and allocation of collateral			(14)
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	585	620	527
Assets fair value disclosure, total	585	620	530
Liabilities fair value disclosure, total	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	(10)	(6)	2
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	6	6	6
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	8	24	11
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	589	620	519
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 2 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	3
Effect of netting and allocation of collateral	0	0	0
Derivative liability	0	0	0
Effect of netting and allocation of collateral			0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Assets fair value disclosure, total	75	127	101
Liabilities fair value disclosure, total	15	52	67
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring | Level 3 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	69	121	95
Effect of netting and allocation of collateral	6	6	6
Derivative liability	15	52	67
Effect of netting and allocation of collateral			0
SoCalGas | Fair Value, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	19	8	18
Liabilities fair value disclosure, total	35	6	4
SoCalGas | Fair Value, Recurring | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of netting and allocation of collateral	18	6	9
Derivative liability	35	6	4
Derivative Asset, Fair Value, Gross Asset	1	2	9
SoCalGas | Fair Value, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	9	2	5
Liabilities fair value disclosure, total	0	0	0
SoCalGas | Fair Value, Recurring | Level 1 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of netting and allocation of collateral	9	1	1
Derivative liability	0	0	0
Derivative Asset, Fair Value, Gross Asset	0	1	4
SoCalGas | Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	10	6	13
Liabilities fair value disclosure, total	35	6	4
SoCalGas | Fair Value, Recurring | Level 2 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of netting and allocation of collateral	9	5	8
Derivative liability	35	6	4
Derivative Asset, Fair Value, Gross Asset	1	1	5
SoCalGas | Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	0	0	0
Liabilities fair value disclosure, total	0	0	0
SoCalGas | Fair Value, Recurring | Level 3 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of netting and allocation of collateral	0	0	0
Derivative liability	0	0	0
Derivative Asset, Fair Value, Gross Asset	$ 0	$ 0	$ 0

FAIR VALUE MEASUREMENTS - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022USD ($)$ / MWh	Dec. 31, 2021USD ($)$ / MWh	Dec. 31, 2020USD ($)$ / MWh	Dec. 31, 2019USD ($)$ / MWh
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 7	$ 3	$ 0
Realized and unrealized gains		11	6
Settlements		(7)	(3)
Ending balance		7	3	$ 0
Change in unrealized gains (losses) relating to instruments still held at the end of the period		11	3
Level 3 | San Diego Gas and Electric Company [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at beginning of period	$ 54	69	28	179
Realized and unrealized (losses) gains		(50)	19	(184)
Allocated transmission instruments		3	6	6
Settlements		32	16	27
Balance at end of period		54	69	28
Change in unrealized gains (losses) relating to derivative instruments still held at the end of the period		$ (16)	$ 34	$ (139)
Level 3 | San Diego Gas and Electric Company [Member] | Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh		(1.81)	(3.77)
Market electricity forward price inputs (in dollars per MWH) | $ / MWh		24.10	19.60	21
Level 3 | San Diego Gas and Electric Company [Member] | Minimum | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	(3.67)
Level 3 | San Diego Gas and Electric Company [Member] | Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh		14.11	6.03
Market electricity forward price inputs (in dollars per MWH) | $ / MWh		105	78.10	61.15
Level 3 | San Diego Gas and Electric Company [Member] | Maximum | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	6.96
Level 3 | San Diego Gas and Electric Company [Member] | Median
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh		(0.12)	(1.58)
Level 3 | San Diego Gas and Electric Company [Member] | Median | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	(0.70)
Level 3 | San Diego Gas and Electric Company [Member] | Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (in dollars per MWH) | $ / MWh		53.57	39.71	37.92
Level 3 | Sempra Infrastructure | Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 7	$ 7
Ending balance		7	$ 7
Level 3 | Sempra Infrastructure | Deferred Credits and Other
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		$ 4
Ending balance			$ 4

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, allowance for credit losses	$ 8
Notes receivable, transaction costs	5
Long term amounts due from unconsolidated affiliates, allowance for credit losses	1	$ 3
Accrued interest receivable	2	3
Unamortized discount (net of premium) and debt issuance costs	260	268	$ 225
Finance lease obligations	1,335	1,330	1,289
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	300
Long-term amounts due from unconsolidated affiliates	640	786	742
Long-term amounts due to unconsolidated affiliates	287	275	195
Total long-term debt	20,099	22,259	21,247
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	327
Long-term amounts due from unconsolidated affiliates	642	817	759
Long-term amounts due to unconsolidated affiliates	295	266	184
Total long-term debt	22,126	25,478	22,664
Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0
Long-term amounts due from unconsolidated affiliates	0	0	0
Long-term amounts due to unconsolidated affiliates	0	0	0
Total long-term debt	0	0	0
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0
Long-term amounts due from unconsolidated affiliates	642	817	759
Long-term amounts due to unconsolidated affiliates	295	266	184
Total long-term debt	22,126	25,478	22,638
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	327
Long-term amounts due from unconsolidated affiliates	0	0	0
Long-term amounts due to unconsolidated affiliates	0	0	0
Total long-term debt	0	0	26
San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	61	52	48
Finance lease obligations	1,274	1,276	1,270
San Diego Gas and Electric Company [Member] | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,417	6,253	5,140
San Diego Gas and Electric Company [Member] | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,236	7,384	5,662
San Diego Gas and Electric Company [Member] | Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0	0
San Diego Gas and Electric Company [Member] | Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,236	7,384	5,662
San Diego Gas and Electric Company [Member] | Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0	0
SoCalGas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	36	40	34
Finance lease obligations	61	54	19
SoCalGas | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,759	4,759	3,809
SoCalGas | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,367	5,655	4,189
SoCalGas | Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0	0
SoCalGas | Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,367	5,655	4,189
SoCalGas | Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0	$ 0

PREFERRED STOCK (Details)

PREFERRED STOCK (Details)	Jun. 19, 2020USD ($)$ / sharesshares	Dec. 31, 2021USD ($)$ / sharesshares	Jul. 15, 2021shares	Jan. 15, 2021shares	Dec. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)shares
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		50,000,000			50,000,000	50,000,000
Sempra Energy
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		50,000,000
San Diego Gas and Electric Company [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		45,000,000			45,000,000	45,000,000
Number of preferred stock shares outstanding (in shares)		0			0
Preferred stock, shares issued (in shares)		0			0
SoCalGas
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		11,000,000			11,000,000	11,000,000
Number of preferred stock shares outstanding (in shares)		1,000,000			1,000,000	1,000,000
Series A Preferred Stock
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)				17,250,000
Shares converted				17,250,000
Convertible Preferred Stock Series A
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					17,250,000	17,250,000
Shares converted				13,781,025
Preferred stock conversion ratio				0.7989
Series B Preferred Stock
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			5,750,000
Shares converted			5,750,000
Series C Preferred Stock
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)		900,000			900,000
Preferred stock, shares issued (in shares)	900,000
Stated percentage rate	4.875%
Preferred stock redemption price (in dollars per share) | $ / shares	$ 1,000
Proceeds from issuance of preferred stock | $	$ 889,000,000
Preferred stock, discount on shares | $	11,000,000
Preferred stock, liquidation preference | $	$ 1,000
Series C Preferred Stock | Period three
Preferred Stock [Line Items]
Preferred stock redemption price (in dollars per share) | $ / shares	$ 1,020
Liquidation preference per share (as a percent)	102.00%
Series C Preferred Stock | Period one
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	4.875%
Liquidation preference (in dollars per share) | $ / shares	$ 1,000
Series C Preferred Stock | Period two
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	4.55%
Liquidation preference (in dollars per share) | $ / shares	$ 1,000
Convertible Preferred Stock Series B
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					5,750,000	5,750,000
Shares converted			4,256,720
Preferred stock conversion ratio			0.7403
So Cal Gas Series Preferred Stock [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		5,000,000
So Cal Gas Series Preferred Stock [Member] | SoCalGas
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		5,000,000
Preferred stock outstanding | $		$ 22,000,000			$ 22,000,000	$ 22,000,000
Twenty Five Dollar Par, Six Percent Series | SoCalGas
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		1,000,000
Number of preferred stock shares outstanding (in shares)		79,011
Par value (in dollars per share) | $ / shares		$ 25
Preferred stock outstanding | $		$ 3,000,000			3,000,000	3,000,000
Twenty Five Dollar Par, Six Percent Series A | SoCalGas
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)		783,032
Liquidation preference (in dollars per share) | $ / shares		$ 25
Preferred stock outstanding | $		$ 19,000,000			19,000,000	19,000,000
So Cal Gas Preferred Stock Owned By Pacific Enterprises
Preferred Stock [Line Items]
Preferred stock outstanding held by parent | $		$ (2,000,000)			(2,000,000)	(2,000,000)
So Cal Gas Preferred Stock Owned By Pacific Enterprises | SoCalGas
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)		50,970
Preferred Stock Of Subsidiaries
Preferred Stock [Line Items]
Preferred stock outstanding | $		$ 20,000,000			$ 20,000,000	$ 20,000,000

SEMPRA - SHAREHOLDERS' EQUITY_3

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - NARRATIVE (Details) - USD ($)	Feb. 25, 2022	Jan. 11, 2022	Nov. 17, 2021	Aug. 04, 2020	Jul. 01, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 06, 2020	Sep. 11, 2007
Shares issued (in shares)						0	0	16,906,185
Issuances of common stock, net						$ 5,000,000	$ 11,000,000	$ 1,830,000,000
Subsequent Event
Maximum amount of shares that may yet be purchased	$ 1,500,000,000
Shares may yet be purchased (in shares)	21,104,486
Common Stock
Stock repurchase program, authorized amount									$ 2,000,000,000	$ 2,000,000,000
Number of shares authorized to be repurchased (in shares)									25,000,000	40,000,000
ASR program, amount prepaid					$ 500,000,000
Common shares repurchased (in shares)			2,422,758	4,089,375
Common shares repurchased, average price (in dollars per share)			$ 123.83	$ 122.27
Common stock acquired (in shares)			$ 300,000,000
Common Stock | Subsequent Event
ASR program, amount prepaid		$ 200,000,000
Common shares repurchased (in shares)		1,472,756
Common shares repurchased, average price (in dollars per share)		$ 135.80
Settlement of Forward Sale Contracts | Common Stock
Shares issued (in shares)								7,156,185
Issuances of common stock, net								$ 728,000,000
Payments of stock issuance costs								$ 13,000,000
Price of shares issued net of underwriting discount (in dollars per share)								$ 101.74
July 2018 Common Stock Offering | Common Stock
Shares issued (in shares)								9,750,000
Issuances of common stock, net								$ 1,066,000,000
Payments of stock issuance costs								$ 18,000,000
Price of shares issued net of underwriting discount (in dollars per share)								$ 109.33

SEMPRA - SHAREHOLDERS' EQUITY_4

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - EARNINGS (LOSSES) PER COMMON SHARE COMPUTATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Income from continuing operations, net of income tax	$ 1,463	$ 2,255	$ 1,999
Earnings attributable to noncontrolling interests	(145)	(162)	(129)
Preferred dividends	(63)	(168)	(142)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings from continuing operations attributable to common shares	1,254	1,924	1,727
Income from discontinued operations, net of income tax	0	1,850	363
Earnings attributable to noncontrolling interests	0	(10)	(35)
Earnings from discontinued operations attributable to common shares	0	1,840	328
Earnings attributable to common shares	1,254	3,764	2,055
Earnings attributable to common shares, diluted	$ 1,254	$ 3,764	$ 2,055
Weighted-average common shares outstanding for basic EPS (in shares)	311,755	291,077	277,904
Dilutive effect of stock options and RSUs (in shares)	752	1,175	1,585
Dilutive effect of common shares sold forward (in shares)	0	0	2,544
Dilutive effect of mandatory convertible preferred stock (in shares)	529	0	0
Weighted-average number of shares outstanding, diluted (in shares)	313,036	292,252	282,033
Earnings from continuing operations attributable to common shares	$ 4.03	$ 6.61	$ 6.22
Earnings (losses) from discontinued operations attributable to common shares	0	6.32	1.18
Basic earnings per common share (in shares)	4.03	12.93	7.40
Earnings from continuing operations (in dollars per share)	4.01	6.58	6.13
Earnings (losses) from discontinued operations (in dollars per share)	0	6.30	1.16
Diluted earnings per common share (in dollars per share)	$ 4.01	$ 12.88	$ 7.29
Fully vested RSUs included in the computation of EPS	453	537	617

SEMPRA - SHAREHOLDERS' EQUITY_5

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - ANTIDILUTIVE SECURITIES EXCLUDED FROM COMPUTATION OF EPS (Details) - shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stock options, RSAs and RSUs
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	211,155	187,028	80,281
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	2,272,117	17,889,365	17,471,375

SEMPRA - SHAREHOLDERS' EQUITY_6

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - COMMON STOCK ACTIVITY (Details) - shares	1 Months Ended	12 Months Ended
	May 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Common stock, shares authorized (in shares)		750,000,000	750,000,000	750,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares outstanding, January 1		288,470,244	291,712,925	273,769,513
Conversion of mandatory convertible preferred stock		18,037,745	0	0
Shares issued in IEnova exchange offer	12,306,777	12,306,777	0	0
Shares issued under forward sale agreements		0	0	16,906,185
RSUs vesting		686,916	896,839	463,012
Stock options exercised		50,671	4,400	52,540
Savings plan issuance		0	201,431	475,774
Common stock investment plan		0	42,955	199,253
Issuance of RSUs held in our Deferred Compensation Plan		102,238	103,552	59,470
Shares repurchased		(2,734,809)	(4,491,858)	(212,822)
Common shares outstanding, December 31		316,919,782	288,470,244	291,712,925

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Period of environmental exit	10 years
Percentage of environmental exit costs incurred	20.00%
San Onofre Nuclear Generating Station (SONGS)
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage	20.00%
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount	$ 78

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Cost	$ 735	$ 731	$ 729
Gross unrealized gains	282	290	360
Gross unrealized losses	(5)	(2)	(7)
Estimated fair value	1,012	1,019	1,082
Proceeds from sales	961	1,439	914
Gross realized gains	67	156	24
Gross realized losses	(5)	(17)	(5)
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	56	64	57
Gross unrealized gains	0	1	0
Gross unrealized losses	0	0	0
Estimated fair value	56	65	57
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	309	308	270
Gross unrealized gains	13	18	12
Gross unrealized losses	(1)	0	0
Estimated fair value	321	326	282
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	255	253	218
Gross unrealized gains	7	17	9
Gross unrealized losses	(2)	0	(1)
Estimated fair value	260	270	226
Debt Securities
Debt Securities, Available-for-sale [Line Items]
Cost	620	625	545
Gross unrealized gains	20	36	21
Gross unrealized losses	(3)	0	(1)
Estimated fair value	637	661	565
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	104	112	176
Gross unrealized gains	262	254	339
Gross unrealized losses	(2)	(2)	(6)
Estimated fair value	364	364	509
Cash and cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	3	3	16
Gross unrealized gains	0	0	0
Gross unrealized losses	0	0	0
Estimated fair value	3	3	16
Accounts Payable
Debt Securities, Available-for-sale [Line Items]
Cost	8	(9)	(8)
Gross unrealized gains	0	0	0
Gross unrealized losses	0	0	0
Estimated fair value	$ 8	$ (9)	$ (8)

SAN ONOFRE NUCLEAR GENERATING_5

SAN ONOFRE NUCLEAR GENERATING STATION - ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Decommissioning liability	$ 568
2022	79
2023	66
2024	77
2025	46
2026	52
Thereafter	$ 718

SAN ONOFRE NUCLEAR GENERATING_6

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Dec. 31, 2021USD ($)
Public Utilities, General Disclosures [Line Items]
Maximum required nuclear liability insurance available	$ 450
Maximum secondary financial protection available	110
Maximum nuclear liability loss coverage per incident	560
Federal nuclear property damage insurance	130
Federal nuclear property damage insurance, minimum required	50
Maximum premium assessment under nuclear property damage insurance	4.3
Maximum nuclear property insurance terrorism coverage	$ 3,240

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) £ in Millions

Feb. 18, 2022lawsuitplaintiff

Nov. 04, 2021USD ($)

Sep. 30, 2021USD ($)

Oct. 31, 2020GBP (£)

Nov. 30, 2019customer

Oct. 31, 2018plaintiff

Jan. 31, 2017lawsuit

Dec. 31, 2021USD ($)claimlawsuit

Dec. 31, 2021GBP (£)

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Sep. 27, 2021USD ($)

Sep. 26, 2021USD ($)

Aug. 31, 2017lawsuit

Oct. 31, 2014USD ($)

Oct. 31, 2014GBP (£)

Loss Contingencies [Line Items]

Loss contingency accrual

$ 2,086,000,000

Number of alleged violations | customer

324

Reserve for Aliso Canyon costs

1,532,000,000

$ 141,000,000

$ (144,000,000)

Reserve for Aliso Canyon costs

1,980,000,000

150,000,000

9,000,000

Income (loss) from equity method investments

614,000,000

294,000,000

30,000,000

Renewable energy transmission and consumption permits

Loss Contingencies [Line Items]

Other intangible assets, net related to self-supply permits

14,000,000

Gas Transmission [Member]

Loss Contingencies [Line Items]

Net book value of pipeline

432,000,000

SoCalGas

Loss Contingencies [Line Items]

Loss contingency accrual

2,006,000,000

Recoverable costs through insurance settlement

1,279,000,000

Reserve for Aliso Canyon costs

1,532,000,000

141,000,000

(144,000,000)

Reserve for Aliso Canyon costs

1,980,000,000

150,000,000

$ 9,000,000

Proceeds from contribution from parent

$ 800,000,000

San Diego Gas and Electric Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

$ 4,000,000

Energy Future Holdings Corp. [Member]

Loss Contingencies [Line Items]

Proof of claims | claim

28,000

Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Loss contingency accrual

484,000,000

Net book value Of Aliso Canyon Natural Gas Storage Facility

$ 883,000,000

Recorded estimated costs

3,221,000,000

Reserve for Aliso Canyon costs

1,983,000,000

Insurance receivable for Aliso Canyon costs

360,000,000

Proceeds from insurance settlement

919,000,000

Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Sempra Energy and Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

$ 1,980,000,000

Shareholder Derivative Complaint [Member] | SoCalGas

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

4

3

HMRC VAT Claim [Member] | R B S Sempra Commodities

Loss Contingencies [Line Items]

VAT tax claim paid upon appeal

$ 138,000,000

HMRC VAT Claim [Member] | Plaintiffs [Member]

Loss Contingencies [Line Items]

Damage awarded

$ 61,000,000

£ 45

Loss Contingency, Costs And Interest Assessed

£ 21

28,000,000

HMRC VAT Claim [Member] | Parent Company

Loss Contingencies [Line Items]

VAT tax claim paid upon appeal | £

£ 86

Consolidated Class Action Complaints [Member]

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

2

Property Class Action [Member]

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

1

Property Class Action [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Estimate of possible loss

$ 40,000,000

Complaints Filed by Firefighters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Number of plaintiffs | plaintiff

51

R B S Sempra Commodities

Loss Contingencies [Line Items]

Energy Efficiency Program Inquiry fines that reduce revenue

50,000,000

Income (loss) from equity method investments

100,000,000

Individual Plaintiff Litigation | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Percentage of plaintiffs represented (as a percent)

80.00%

Estimate of possible loss

$ 1,800,000,000

Acceptance rate of plaintiffs (as a percent)

97.00%

Business Class Action | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Estimate of possible loss

$ 100,000

Proposition 65 Claims | SoCalGas

Loss Contingencies [Line Items]

Energy Efficiency Program Inquiry fines that reduce revenue

$ 2,000,000

Subsequent Event | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

390

Number of plaintiffs | plaintiff

36,000

Insurance Receivable for Aliso Canyon Costs [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Loss contingency accrual

177,000,000

Aliso Canyon Litigation and Regulatory Matters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

307,000,000

Aliso Canyon Litigation and Regulatory Matters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | SoCalGas

Loss Contingencies [Line Items]

Loss contingency accrual

1,590,000,000

307,000,000

Loss accrual, net of tax

$ 1,150,000,000

$ 233,000,000

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - LEASES BALANCE SHEET INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 594	$ 543	$ 591
Finance leases, property plant and equipment	1,473	1,429	1,353
Finance leases, accumulated depreciation	$ (138)	$ (99)	$ (64)
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant and equipment, net	Property, plant and equipment, net	Property, plant and equipment, net
Finance leases, property plant and equipment, net	$ 1,335	$ 1,330	$ 1,289
Lease, Right-of-Use Asset	$ 1,929	$ 1,873	$ 1,880
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other current liabilities	Other current liabilities	Other current liabilities
Operating lease, other current liabilities	$ 49	$ 52	$ 52
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Deferred credits and other	Deferred credits and other	Deferred credits and other
Operating lease, deferred credits and other	$ 470	$ 407	$ 445
Total lease liabilities	$ 519	$ 459	$ 497
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Current portion of long-term debt and finance leases	Current portion of long-term debt and finance leases	Current portion of long-term debt and finance leases
Finance lease, current portion of long-term debt and finance leases	$ 43	$ 36	$ 26
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Long-term debt	Long-term debt	Long-term debt
Long-term lease liabilities	$ 1,292	$ 1,294	$ 1,263
Total finance leases	1,335	1,330	1,289
Lease liabilities	$ 1,854	$ 1,789	$ 1,786
Operating lease, weighted-average remaining lease term	14 years	13 years	13 years
Finance lease, weighted-average remaining lease term	17 years	18 years	19 years
Operating lease, weighted-average discount rate (as a percent)	5.45%	5.81%	6.01%
Finance lease, weighted-average discount rate (as a percent)	14.25%	14.45%	14.76%
SDG&E
Lessee, Lease, Description [Line Items]
Variable payments, due in 2022	$ 297
Variable payments, due in 2023	296
Variable payments, due in 2024	297
Variable payments, due in 2025	296
Variable payments, due in 2026	290
Variable payments, due thereafter	2,779
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	185	$ 102	$ 130
Finance leases, property plant and equipment	1,381	1,356	1,326
Finance leases, accumulated depreciation	(107)	(80)	(57)
Finance leases, property plant and equipment, net	1,274	1,276	1,269
Lease, Right-of-Use Asset	1,459	1,378	1,399
Operating lease, other current liabilities	26	27	27
Operating lease, deferred credits and other	159	73	102
Total lease liabilities	185	100	129
Finance lease, current portion of long-term debt and finance leases	32	26	20
Long-term lease liabilities	1,242	1,250	1,250
Total finance leases	1,274	1,276	1,270
Lease liabilities	$ 1,459	$ 1,376	$ 1,399
Operating lease, weighted-average remaining lease term	11 years	6 years	6 years
Finance lease, weighted-average remaining lease term	17 years	19 years	20 years
Operating lease, weighted-average discount rate (as a percent)	3.22%	3.62%	3.55%
Finance lease, weighted-average discount rate (as a percent)	14.48%	14.65%	14.83%
SoCalGas
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 57	$ 74	$ 94
Finance leases, property plant and equipment	92	73	27
Finance leases, accumulated depreciation	(31)	(19)	(7)
Finance leases, property plant and equipment, net	61	54	20
Lease, Right-of-Use Asset	118	128	114
Operating lease, other current liabilities	15	18	18
Operating lease, deferred credits and other	41	56	75
Total lease liabilities	56	74	93
Finance lease, current portion of long-term debt and finance leases	11	10	6
Long-term lease liabilities	50	44	13
Total finance leases	61	54	19
Lease liabilities	$ 117	$ 128	$ 112
Operating lease, weighted-average remaining lease term	4 years	5 years	6 years
Finance lease, weighted-average remaining lease term	7 years	7 years	6 years
Operating lease, weighted-average discount rate (as a percent)	1.98%	2.03%	3.73%
Finance lease, weighted-average discount rate (as a percent)	2.91%	2.83%	3.23%
Maximum
Lessee, Lease, Description [Line Items]
Operating lease renewal period	20 years
Annual increase in rent, percent	5.00%
Minimum
Lessee, Lease, Description [Line Items]
Operating lease termination period	1 year
Annual increase in rent, percent	2.00%

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - LEASE INCOME STATEMENT INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 89	$ 92	$ 96
Amortization of ROU assets	39	35	24
Interest on lease liabilities	186	188	173
Total finance lease costs	225	223	197
Short-term lease costs	7	7	6
Variable lease costs	432	477	482
Total lease costs	753	799	781
Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	22	18	15
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	32	31	33
Amortization of ROU assets	27	23	18
Interest on lease liabilities	184	186	173
Total finance lease costs	211	209	191
Short-term lease costs	1	3	2
Variable lease costs	422	467	471
Total lease costs	666	710	697
San Diego Gas and Electric Company [Member] | Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	21	18	15
SoCalGas
Lessee, Lease, Description [Line Items]
Operating lease costs	20	24	27
Amortization of ROU assets	12	12	6
Interest on lease liabilities	2	2	0
Total finance lease costs	14	14	6
Short-term lease costs	0	0	0
Variable lease costs	10	10	10
Total lease costs	44	$ 48	$ 43
SoCalGas | Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	$ 1

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LEASES CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 78	$ 79	$ 101
Cash paid for finance leases	171	173	173
Cash paid for finance leases	39	35	24
Increase (decrease) in operating lease obligations for ROU assets	116	20	585
Increase in finance lease obligations for investment in PP&E	43	77	38
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	32	31	33
Cash paid for finance leases	169	171	173
Cash paid for finance leases	27	23	18
Increase (decrease) in operating lease obligations for ROU assets	112	(1)	158
Increase in finance lease obligations for investment in PP&E	24	30	16
SoCalGas
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	20	24	27
Cash paid for finance leases	2	2	0
Cash paid for finance leases	12	12	6
Increase (decrease) in operating lease obligations for ROU assets	1	1	118
Increase in finance lease obligations for investment in PP&E	$ 19	$ 47	$ 22

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY ANALYSIS OF LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating leases(1)
2022	$ 73
2023	66
2024	62
2025	50
2026	48
Thereafter	493
Total undiscounted lease payments	792
Less: imputed interest	(273)
Total lease liabilities	519	$ 459	$ 497
Less: current lease liabilities	(49)	(52)	(52)
Long-term lease liabilities	470	407	445
Finance leases
2022	209
2023	208
2024	203
2025	199
2026	196
Thereafter	2,292
Total undiscounted lease payments	3,307
Less: imputed interest	(1,972)
Total finance leases	1,335	1,330	1,289
Less: current lease liabilities	(43)	(36)	(26)
Long-term lease liabilities	1,292	1,294	1,263
Purchased-Power Contracts
Operating leases(1)
2022	9
2023	9
2024	9
2025	9
2026	9
Thereafter	87
San Diego Gas and Electric Company [Member]
Operating leases(1)
2022	30
2023	27
2024	25
2025	16
2026	15
Thereafter	105
Total undiscounted lease payments	218
Less: imputed interest	(33)
Total lease liabilities	185	100	129
Less: current lease liabilities	(26)	(27)	(27)
Long-term lease liabilities	159	73	102
Finance leases
2022	197
2023	197
2024	192
2025	188
2026	188
Thereafter	2,279
Total undiscounted lease payments	3,241
Less: imputed interest	(1,967)
Total finance leases	1,274	1,276	1,270
Less: current lease liabilities	(32)	(26)	(20)
Long-term lease liabilities	1,242	1,250	1,250
SoCalGas
Operating leases(1)
2022	17
2023	13
2024	11
2025	10
2026	8
Thereafter	0
Total undiscounted lease payments	59
Less: imputed interest	(3)
Total lease liabilities	56	74	93
Less: current lease liabilities	(15)	(18)	(18)
Long-term lease liabilities	41	56	75
Finance leases
2022	12
2023	11
2024	11
2025	11
2026	8
Thereafter	13
Total undiscounted lease payments	66
Less: imputed interest	(5)
Total finance leases	61	54	19
Less: current lease liabilities	(11)	(10)	(6)
Long-term lease liabilities	$ 50	$ 44	$ 13

COMMITMENTS AND CONTINGENCIES_6

COMMITMENTS AND CONTINGENCIES - LEASES THAT HAVE NOT YET COMMENCED (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Lease not yet commenced, due in 2022	$ 8
Lease not yet commenced, due in 2023	17
Lease not yet commenced, due in 2024	18
Lease not yet commenced, due in 2025	18
Lease not yet commenced, due in 2026	18
Lease not yet commenced, due thereafter	101
SoCalGas
Lessee, Lease, Description [Line Items]
Lease not yet commenced, due in 2022	1
Lease not yet commenced, due in 2023	2
Lease not yet commenced, due in 2024	2
Lease not yet commenced, due in 2025	2
Lease not yet commenced, due in 2026	2
Lease not yet commenced, due thereafter	$ 6

COMMITMENTS AND CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessor, Lease, Description [Line Items]
Property, plant and equipment		$ 58,940	$ 53,928	$ 49,329
Accumulated depreciation		(15,046)	(13,925)	(12,877)
Property, plant and equipment, net		43,894	40,003	36,452
Operating leases
2022		272
2023		272
2024		273
2025		272
2026		272
Thereafter		3,031
Total undiscounted cash flows		4,392
Fixed lease payments		256	195	200
Variable lease payments		10	1	6
Total revenues from operating leases		266	196	206
Depreciation expense		1,833	1,646	1,551
Sales-type leases
2022		16
2023		16
2024		17
2025		17
2026		9
Thereafter		0
Total undiscounted cash flows		75
Present value of lease payments (recognized as lease receivable)		55
Difference between undiscounted cash flows and discounted cash flows		20
Income recognized at lease commencement		18	1	0
Interest income		4	1	0
Total revenues from sales-type lease		22	2	0
Other current assets
Sales-type leases
Present value of lease payments (recognized as lease receivable)		9
Other long-term assets
Sales-type leases
Present value of lease payments (recognized as lease receivable)		46
Sempra Infrastructure
Lessor, Lease, Description [Line Items]
Carrying value	$ 44
Net investment in lease	62
Selling profit	$ 18
Operating Leases, Assets
Lessor, Lease, Description [Line Items]
Property, plant and equipment		1,499	1,092	1,038
Accumulated depreciation		(276)	(228)	(179)
Property, plant and equipment, net		1,223	864	859
Operating leases
Depreciation expense		$ 48	$ 39	$ 38

COMMITMENTS AND CONTINGENCIES_8

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Variable payments, due in 2022	$ 297
Variable payments, due in 2023	296
Variable payments, due in 2024	297
Variable payments, due in 2025	296
Variable payments, due in 2026	290
Variable payments, due thereafter	2,779
Storage and transportation
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	214
2023	204
2024	181
2025	141
2026	137
Thereafter	903
Total minimum payments	1,780
Natural Gas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	20
2023	39
2024	15
2025	7
2026	0
Thereafter	0
Total minimum payments	81
Natural Gas Contracts
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	234
2023	243
2024	196
2025	148
2026	137
Thereafter	903
Total minimum payments	1,861
Payments	1,691	$ 989	$ 1,326
Natural Gas Contracts | SoCalGas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Payments	1,590	935	1,181
Transportation | SoCalGas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	134
2023	132
2024	114
2025	77
2026	75
Thereafter	310
Total minimum payments	842
Liquefied Natural Gas Contracts | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	435
2023	553
2024	516
2025	518
2026	519
Thereafter	1,381
Total minimum payments	3,922
Payments	$ 27	16	17
Long-term Contracts | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	60.00%
Renewable Energy Contracts | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	57.00%
Other Owned Generation | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	46.00%
Spot Market Purchases (Sales) | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	(6.00%)
Purchased-Power Contracts
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	$ 218
2023	188
2024	162
2025	105
2026	100
Thereafter	817
Total minimum payments	1,590
Purchased-Power Contracts | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	218
2023	188
2024	162
2025	105
2026	100
Thereafter	817
Total minimum payments	1,590
Variable payments, due in 2022	63
Variable payments, due in 2023	63
Variable payments, due in 2024	63
Variable payments, due in 2025	63
Variable payments, due in 2026	63
Variable payments, due thereafter	430
Payments	495	$ 534	$ 744
Infrastructure Construction And Improvements
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	223
2023	22
2024	18
2025	18
2026	5
Thereafter	103
Total minimum payments	389
Infrastructure Construction And Improvements | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	3
2023	3
2024	1
2025	1
2026	1
Thereafter	18
Construction projects, payable	27
Infrastructure Construction And Improvements | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	220
2023	19
2024	17
2025	17
2026	4
Thereafter	85
Total minimum payments	362
Infrastructure Improvements For Natural Gas And Electric Transmission And Distribution | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	4
Nuclear Plant Maintenance | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	23
Liquid fuels terminals | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	43
Natural Gas Pipelines and Ongoing Maintenance Services | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	296
Renewables Projects | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	$ 23

COMMITMENTS AND CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - OTHER COMMITMENTS (Details)	Jun. 08, 2021USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2012USD ($)MMcf
Natural Gas and Electric Franchise | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Expected payment		$ 14,000,000
Expected payment, due in second year		14,000,000
Expected payment, due in third year		14,000,000
Expected payment, due in fourth year		15,000,000
Expected payment, due in fifth year		4,000,000
Expected payment, thereafter		51,000,000
Other Commitment	$ 110,000,000
Other Commitments, Interest Payments	$ 13,000,000
Other Commitments, Payments		11,000,000
Sunrise Powerlink Construction | SDG&E
Loss Contingencies [Line Items]
Expected payment		4,000,000
Expected payment, due in second year		4,000,000
Expected payment, due in third year		4,000,000
Expected payment, due in fourth year		4,000,000
Expected payment, due in fifth year		4,000,000
Expected payment, thereafter		$ 275,000,000
Estimated annual escalation		2.00%
Purchase commitment period		48 years
Present value of future payments		$ 122,000,000
Continental Forge | Sempra Infrastructure
Loss Contingencies [Line Items]
Purchase commitment period			18 years
Amount o natural gas to be sold (MMcf per day) | MMcf			500
Price index			$ 0.02

COMMITMENTS AND CONTINGENCIE_10

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)site	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Environmental Issues [Line Items]
Capital expendistures for environmental issues	$ 95	$ 76	$ 80
Accrued liability for environmental matters, discount	$ 9
Accrued liability for environmental matters, discount rate (as a percent)	1.50%
Accrual for environmental loss contingencies	$ 57
Expected future payments for accruals, 2022	6
Expected future payments for accruals, 2023	13
Expected future payments for accruals, 2024	9
Expected future payments for accruals, 2025	4
Expected future payments for accruals, 2026	17
Expected future payments for accruals, thereafter	53
Minimum
Environmental Issues [Line Items]
Potential monetary sanctions threshold	1
Sempra Energy
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	44
Accrual for environmental loss contingencies, current	5
Accrual for environmental loss contingencies, noncurrent	52
San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	14
Capital expendistures for environmental issues	32	39	39
Accrual for environmental loss contingencies	18
Accrual for environmental loss contingencies, current	2
Accrual for environmental loss contingencies, noncurrent	16
SoCalGas
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	16
Capital expendistures for environmental issues	63	$ 37	$ 41
Accrued liability for environmental matters, discount	$ 9
Accrued liability for environmental matters, discount rate (as a percent)	1.50%
Accrual for environmental loss contingencies	$ 38
Accrual for environmental loss contingencies, current	3
Accrual for environmental loss contingencies, noncurrent	35
Other Sempra
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Manufactured-gas sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 34
Manufactured-gas sites | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	3
Number of sites in process | site	0
Accrual for environmental loss contingencies	$ 0
Manufactured-gas sites | SoCalGas
Environmental Issues [Line Items]
Number of sites complete | site	39
Number of sites in process | site	3
Accrual for environmental loss contingencies	$ 34
Manufactured-gas sites | Other Sempra
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	0
Waste Disposal Sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 10
Waste Disposal Sites | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	2
Number of sites in process | site	1
Accrual for environmental loss contingencies	$ 6
Waste Disposal Sites | SoCalGas
Environmental Issues [Line Items]
Number of sites complete | site	5
Number of sites in process | site	2
Accrual for environmental loss contingencies	$ 3
Waste Disposal Sites | Other Sempra
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Other hazardous waste sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	13
Other hazardous waste sites | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	12
Other hazardous waste sites | SoCalGas
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Other hazardous waste sites | Other Sempra
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	0
SONGS Sites | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	97
SONGS mitigation costs incurred	53
SONGS mitigation costs remaining	$ 44

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Millions	12 Months Ended			21 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2020USD ($)segment	Oct. 01, 2021	Sep. 30, 2021	May 31, 2021	Apr. 30, 2021	May 16, 2019
Segment Reporting Information [Line Items]
Number of reportable segments | segment				4
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 12,857	$ 11,370	$ 10,829
DEPRECIATION AND AMORTIZATION	1,855	1,666	1,569
INTEREST INCOME	69	96	87
INTEREST EXPENSE	1,198	1,081	1,077
Income tax expense (benefit)	99	249	315
Earnings (losses) attributable to common shares	1,254	3,764	2,055
Earnings from discontinued operations attributable to common shares	0	1,840	328
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	5,015	4,676	3,708
ASSETS	72,045	66,623	65,665	$ 66,623
Long-lived assets	58,366	53,831	50,074	53,831
United States
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	11,154	10,205	9,574
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	50,657	46,902	43,719	46,902
Mexico
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,703	1,165	1,255
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	7,708	6,929	6,355	6,929
Asia
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	1	0	0	0
Operating Segments | SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5,504	5,313	4,925
DEPRECIATION AND AMORTIZATION	889	801	760
INTEREST INCOME	1	2	4
INTEREST EXPENSE	412	413	411
Income tax expense (benefit)	201	190	171
Earnings (losses) attributable to common shares	819	824	767
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	2,220	1,942	1,522
ASSETS	24,058	22,311	20,560	22,311
Operating Segments | SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5,515	4,748	4,525
DEPRECIATION AND AMORTIZATION	716	654	602
INTEREST INCOME	1	2	2
INTEREST EXPENSE	157	158	141
Income tax expense (benefit)	(310)	96	120
Earnings (losses) attributable to common shares	(427)	504	641
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	1,984	1,843	1,439
ASSETS	20,324	18,460	17,077	18,460
Operating Segments | Sempra Texas Utilities
Segment Reporting Information, Profit (Loss) [Abstract]
Income tax expense (benefit)	0	1	0
Earnings (losses) attributable to common shares	616	579	528
Segment Reporting Information, Additional Information [Abstract]
ASSETS	13,047	12,542	11,619	12,542
Operating Segments | Sempra Renewables
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0	0	10
INTEREST INCOME	0	0	11
INTEREST EXPENSE	0	0	3
Income tax expense (benefit)	0	0	4
Earnings (losses) attributable to common shares	0	0	59
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	0	0	2
Operating Segments | Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,997	1,400	1,454
DEPRECIATION AND AMORTIZATION	239	198	193
INTEREST INCOME	75	141	139
INTEREST EXPENSE	205	174	155
Income tax expense (benefit)	238	149	222
Earnings (losses) attributable to common shares	682	580	247
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	802	879	736
ASSETS	14,408	12,772	13,660	12,772
Adjustment and Elimination [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(1)	(3)	(3)
Earnings from discontinued operations attributable to common shares	0	1,840	328
Segment Reporting Information, Additional Information [Abstract]
Assets, discontinued operations	0	0	3,958	0
Intersegment Eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(163)	(90)	(85)
INTEREST INCOME	(11)	(56)	(73)
INTEREST EXPENSE	(20)	(54)	(83)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,191)	(677)	(1,972)	(677)
Intersegment Eliminations [Member] | SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	10	5	5
Intersegment Eliminations [Member] | SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	98	88	69
Intersegment Eliminations [Member] | Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	55	(3)	11
All Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5	2	3
DEPRECIATION AND AMORTIZATION	11	13	14
INTEREST INCOME	3	7	4
INTEREST EXPENSE	444	390	450
Income tax expense (benefit)	(30)	(187)	(202)
Earnings (losses) attributable to common shares	(436)	(563)	(515)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	9	12	9
ASSETS	$ 1,399	$ 1,215	$ 763	$ 1,215
Sempra LNG Holding, LP | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	100.00%
IEnova
Segment Reporting Information [Line Items]
Ownership interest (as a percent)					99.90%	99.90%	96.40%	70.20%
IEnova | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	99.90%
SI Partners | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	80.00%
Oncor Holdings | Oncor Electric Delivery Company LLC | Sempra Texas Utilities
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	80.25%
Sharyland Holdings, LP
Segment Reporting Information [Line Items]
Acquired percentage interest									50.00%
Sharyland Holdings, LP | Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest									50.00%

SCHEDULE I - CONDENSED FINANC_3

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF OPERATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Income Statements, Captions [Line Items]
Interest income	$ 69	$ 96	$ 87
Interest expense	(1,198)	(1,081)	(1,077)
Other income (expense), net	58	(48)	77
Income tax benefit (expense)	(99)	(249)	(315)
Income from continuing operations, net of tax	1,463	2,255	1,999
Net income	$ 1,463	$ 4,105	$ 2,362
Basic earnings per common share (in shares)	$ 4.03	$ 12.93	$ 7.40
Weighted-average number of shares outstanding, basic (in shares)	311,755	291,077	277,904
Diluted earnings per common share (in dollars per share)	$ 4.01	$ 12.88	$ 7.29
Weighted-average number of shares outstanding, diluted (in shares)	313,036	292,252	282,033
Parent Company
Condensed Income Statements, Captions [Line Items]
Interest income	$ 11	$ 4	$ 3
Interest expense	(576)	(495)	(521)
Operating expenses	(92)	(86)	(124)
Other income (expense), net	20	(38)	59
Income tax benefit (expense)	190	176	163
Income from continuing operations, net of tax	(447)	(439)	(420)
Equity in earnings of subsidiaries, net of income taxes	1,764	4,371	2,617
Net income	1,317	3,932	2,197
Preferred dividends	(63)	(168)	(142)
Earnings attributable to common shares	$ 1,254	$ 3,764	$ 2,055
Basic earnings per common share (in shares)	$ 4.03	$ 12.93	$ 7.40
Weighted-average number of shares outstanding, basic (in shares)	311,755	291,077	277,904
Diluted earnings per common share (in dollars per share)	$ 4.01	$ 12.88	$ 7.29
Weighted-average number of shares outstanding, diluted (in shares)	313,036	292,252	282,033

SCHEDULE I - CONDENSED FINANC_4

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Statement of Income Captions [Line Items]
Net income	$ 1,463	$ 4,105	$ 2,362
Total other comprehensive (loss) income	171	422	(140)
Pretax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,417	5,368	2,585
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Total comprehensive income, after preferred dividends of subsidiaries	1,629	5,779	2,405
Income tax benefit (expense)
Condensed Statement of Income Captions [Line Items]
Net income	(99)	(1,435)	(387)
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Total comprehensive income, after preferred dividends of subsidiaries	(152)	(1,401)	(341)
Net-of-tax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,318	3,933	2,198
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Total comprehensive income, after preferred dividends of subsidiaries	1,477	4,378	2,064
Parent Company
Condensed Statement of Income Captions [Line Items]
Net income	1,317	3,932	2,197
Parent Company | Pretax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,127	3,756	2,034
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Total comprehensive income, after preferred dividends of subsidiaries	1,340	4,168	1,855
Parent Company | Income tax benefit (expense)
Condensed Statement of Income Captions [Line Items]
Net income	190	176	163
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Total comprehensive income, after preferred dividends of subsidiaries	137	210	209
Parent Company | Net-of-tax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,317	3,932	2,197
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Total comprehensive income, after preferred dividends of subsidiaries	$ 1,477	$ 4,378	$ 2,064

SCHEDULE I - CONDENSED FINANC_5

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
ASSETS
Cash and cash equivalents	$ 559	$ 960	$ 108
Due from affiliates	23	20	32
Income taxes receivable	79	113	112
Other current assets	209	149	163
Total current assets	4,375	4,511	3,339
Due from affiliates	637	780	742
Deferred income taxes	151	136	155
Other long-term assets	1,244	753	732
Total assets	72,045	66,623	65,665
Liabilities and shareholders’ equity:
Short-term debt	3,471	885	3,505
Current portion of long-term debt	106	1,540	1,526
Due to affiliates	0	45	5
Other current liabilities	1,131	1,016	866
Total current liabilities	10,035	6,839	9,150
Long-term debt	21,068	21,781	20,785
Due to affiliates	287	234	195
Commitments and contingencies (Note 4)
Total shareholders’ equity	25,981	23,373	19,929
Total liabilities and shareholders’ equity	72,045	66,623	65,665
Parent Company
ASSETS
Cash and cash equivalents	186	366	6
Restricted cash	2	0	0
Due from affiliates	446	58	98
Income taxes receivable	0	42	0
Other current assets	31	26	34
Total current assets	665	492	138
Investments in subsidiaries	33,308	33,898	32,604
Due from affiliates	21	1	3
Deferred income taxes	626	2,187	1,766
Other long-term assets	1,090	717	682
Total assets	35,710	37,295	35,193
Liabilities and shareholders’ equity:
Short-term debt	1,240	0	0
Current portion of long-term debt	0	850	1,399
Due to affiliates	185	224	369
Income taxes payable, net	4	0	274
Other current liabilities	531	536	561
Total current liabilities	1,960	1,610	2,603
Long-term debt	5,969	7,317	8,856
Due to affiliates	1,151	4,375	3,138
Other long-term liabilities	649	620	667
Commitments and contingencies (Note 4)
Total shareholders’ equity	25,981	23,373	19,929
Total liabilities and shareholders’ equity	$ 35,710	$ 37,295	$ 35,193

SCHEDULE I - CONDENSED FINANC_6

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	$ 3,842	$ 2,591	$ 3,088
Expenditures for property, plant and equipment	(5,015)	(4,676)	(3,708)
Disbursement for note receivable	(305)	0	0
Distributions from investments	941	651	247
Other	11	15	21
Net cash (used in) provided by investing activities	(5,508)	553	(4,593)
Common stock dividends paid	(1,331)	(1,174)	(993)
Preferred dividends paid	(99)	(157)	(142)
Proceeds from Issuance of Preferred Stock and Preference Stock	0	891	0
Issuances of common stock, net	5	11	1,830
Repurchases of common stock	(339)	(566)	(26)
Issuances of long-term debt	3,773	6,051	4,296
Payments on long-term debt	(5,489)	(5,864)	(3,667)
Increase in loans from affiliates, net	38	7	3
Purchases of noncontrolling interest	(224)	(248)	(30)
Other	(199)	(50)	(49)
Net cash provided by financing activities	1,260	(2,373)	1,475
Effect of exchange rate changes in continuing operations	2	0	0
Increase (decrease) in cash and cash equivalents	(404)	768	(29)
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Common dividends issued in stock	0	22	55
Conversion of mandatory convertible preferred stock	2,258	0	0
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	(255)	(978)	294
Expenditures for property, plant and equipment	(8)	(9)	(8)
Capital contributions to investees	(1,005)	(364)	(1,528)
Disbursement for note receivable	(305)	0	0
Distributions from investments	1,552	3,616	0
(Increase) decrease in loans to affiliates, net	(20)	2	0
Other	0	0	4
Net cash (used in) provided by investing activities	214	3,245	(1,532)
Common stock dividends paid	(1,331)	(1,174)	(993)
Preferred dividends paid	(99)	(157)	(142)
Proceeds from Issuance of Preferred Stock and Preference Stock	0	891	0
Issuances of common stock, net	5	11	1,830
Repurchases of common stock	(339)	(566)	(26)
Issuances of long-term debt	990	1,599	758
Payments on long-term debt	(3,200)	(3,700)	(1,500)
Increase in short-term debt	1,240	0	0
Increase in loans from affiliates, net	1,092	1,194	1,328
Purchases of noncontrolling interest	(217)	0	0
Proceeds from sale of noncontrolling interest	1,846	0	0
Equity transaction costs with third parties	0	(4)	0
Debt issuance costs	0	(1)	(25)
Make-whole premiums related to early redemptions of debt	(121)	0	0
Other	(2)	0	0
Net cash provided by financing activities	(136)	(1,907)	1,230
Effect of exchange rate changes in continuing operations	(1)	0	0
Increase (decrease) in cash and cash equivalents	(178)	360	(8)
Cash and cash equivalents, January 1	366	6	14
Cash and cash equivalents, December 31	188	366	6
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Issuance of common stock in exchange for NCI and related AOCI	1,373	0	0
Common dividends issued in stock	0	22	55
Common dividends declared but not paid	349	301	283
Conversion of mandatory convertible preferred stock	2,258	0	0
Preferred dividends declared but not paid	11	47	36
Equitization of amounts due from affiliates	$ 4,351	$ 0	$ 0

SCHEDULE I - CONDENSED FINANC_7

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - FOOTNOTES (Details)	1 Months Ended		12 Months Ended
	Dec. 31, 2021USD ($)lender	Nov. 30, 2021USD ($)	Dec. 31, 2021USD ($)lender	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Debt Instruments [Abstract]
Total facility	$ 9,535,000,000		$ 9,535,000,000
Letters of credit outstanding	682,000,000		682,000,000
Current portion of long-term debt	(106,000,000)		(106,000,000)	$ (1,540,000,000)	$ (1,526,000,000)
Long-term debt	21,068,000,000		21,068,000,000	21,781,000,000	20,785,000,000
Long term debt maturities after 2026	16,397,000,000		16,397,000,000
Operating leases(1)
Total operating lease commitments	792,000,000		792,000,000
2022	73,000,000		73,000,000
2023	66,000,000		66,000,000
2024	62,000,000		62,000,000
2025	50,000,000		50,000,000
Thereafter	493,000,000		493,000,000
Letter of Credit
Debt Instruments [Abstract]
Long-term debt outstanding	682,000,000		682,000,000
Parent Company
Debt Instruments [Abstract]
Gross long-term debt	6,058,000,000		6,058,000,000	8,258,000,000	10,358,000,000
Current portion of long-term debt	0		0	(850,000,000)	(1,399,000,000)
Unamortized discount on long-term debt	(37,000,000)		(37,000,000)	(32,000,000)	(35,000,000)
Unamortized debt issuance costs	(52,000,000)		(52,000,000)	(59,000,000)	(68,000,000)
Long-term debt	5,969,000,000		5,969,000,000	7,317,000,000	8,856,000,000
Long term debt maturities after 2026	6,100,000,000		6,100,000,000
Operating leases(1)
Total operating lease commitments	279,000,000		279,000,000
2022	11,000,000		11,000,000
2023	12,000,000		12,000,000
2024	12,000,000		12,000,000
2025	12,000,000		12,000,000
Thereafter	$ 220,000,000		$ 220,000,000
Parent Company | 2.4% Notes February 1, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.40%		2.40%
Gross long-term debt	$ 0		$ 0	0	500,000,000
Parent Company | 2.4% Notes March 15, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.40%		2.40%
Gross long-term debt	$ 0		$ 0	0	500,000,000
Parent Company | 2.85% Notes November 15, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.85%		2.85%
Gross long-term debt	$ 0		$ 0	0	400,000,000
Parent Company | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Gross long-term debt	$ 0		$ 0	0	700,000,000
Parent Company | Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021
Debt Instruments [Abstract]
Fixed interest rate after floating to fixed interest rate swaps	3.069%		3.069%
Gross long-term debt	$ 0		$ 0	850,000,000	850,000,000
Parent Company | 2.875% Notes October 1, 2022
Debt Instruments [Abstract]
Stated percentage rate	2.875%		2.875%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company | 2.9% Notes February 1, 2023
Debt Instruments [Abstract]
Stated percentage rate	2.90%		2.90%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company | 4.05% Notes December 1, 2023
Debt Instruments [Abstract]
Stated percentage rate	4.05%		4.05%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company | 3.55% Notes June 15, 2024
Debt Instruments [Abstract]
Stated percentage rate	3.55%		3.55%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company | 3.75% Notes November 15, 2025
Debt Instruments [Abstract]
Stated percentage rate	3.75%		3.75%
Gross long-term debt	$ 0		$ 0	350,000,000	350,000,000
Parent Company | 3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate	3.25%		3.25%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Parent Company | 3.4% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate	3.40%		3.40%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Parent Company | 3.8% Notes February 1, 2038
Debt Instruments [Abstract]
Stated percentage rate	3.80%		3.80%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Parent Company | 6% Notes October 15, 2039
Debt Instruments [Abstract]
Stated percentage rate	6.00%		6.00%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Parent Company | 4% Notes February 1, 2048
Debt Instruments [Abstract]
Stated percentage rate	4.00%		4.00%
Gross long-term debt	$ 800,000,000		$ 800,000,000	800,000,000	800,000,000
Parent Company | 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instruments [Abstract]
Stated percentage rate	4.125%	4.125%	4.125%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	0	0
Proceeds from issuance of debt		$ 988,000,000
Underwriting discounts and debt issuance costs		12,000,000
Debt amount		1,000,000,000
Repayments of senior notes		$ 2,350,000,000
Parent Company | 5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instruments [Abstract]
Stated percentage rate	5.75%		5.75%
Gross long-term debt	$ 758,000,000		$ 758,000,000	758,000,000	$ 758,000,000
Sempra Energy
Debt Instruments [Abstract]
Total facility	3,185,000,000		3,185,000,000
Sempra Energy | 2.4% Notes February 1, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.40%
Gross long-term debt	0		0	0	$ 500,000,000
Sempra Energy | 2.4% Notes March 15, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.40%
Gross long-term debt	0		0	0	$ 500,000,000
Sempra Energy | 2.85% Notes November 15, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.85%
Gross long-term debt	0		0	0	$ 400,000,000
Sempra Energy | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Gross long-term debt	0		0	$ 0	700,000,000
Sempra Energy | Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021
Debt Instruments [Abstract]
Fixed interest rate after floating to fixed interest rate swaps				3.069%
Gross long-term debt	0		0	$ 850,000,000	850,000,000
Sempra Energy | 2.875% Notes October 1, 2022
Debt Instruments [Abstract]
Stated percentage rate				2.875%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
Sempra Energy | 2.9% Notes February 1, 2023
Debt Instruments [Abstract]
Stated percentage rate				2.90%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
Sempra Energy | 4.05% Notes December 1, 2023
Debt Instruments [Abstract]
Stated percentage rate				4.05%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
Sempra Energy | 3.55% Notes June 15, 2024
Debt Instruments [Abstract]
Stated percentage rate				3.55%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
Sempra Energy | 3.75% Notes November 15, 2025
Debt Instruments [Abstract]
Stated percentage rate				3.75%
Gross long-term debt	$ 0		$ 0	$ 350,000,000	350,000,000
Sempra Energy | 3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate	3.25%		3.25%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Sempra Energy | 3.4% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate	3.40%		3.40%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Sempra Energy | 3.8% Notes February 1, 2038
Debt Instruments [Abstract]
Stated percentage rate	3.80%		3.80%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Sempra Energy | 6% Notes October 15, 2039
Debt Instruments [Abstract]
Stated percentage rate	6.00%		6.00%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Sempra Energy | 4% Notes February 1, 2048
Debt Instruments [Abstract]
Stated percentage rate	4.00%		4.00%
Gross long-term debt	$ 800,000,000		$ 800,000,000	800,000,000	800,000,000
Sempra Energy | 5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instruments [Abstract]
Stated percentage rate	5.75%		5.75%
Gross long-term debt	$ 758,000,000		$ 758,000,000	758,000,000	758,000,000
Sempra Energy | Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instruments [Abstract]
Underwriting discounts and debt issuance costs	126,000,000		126,000,000
Debt issuance costs (after tax)	92,000,000		92,000,000
Sempra Energy | Parent Company
Basis of Presentation
Cash dividends received			375,000,000	$ 300,000,000	$ 150,000,000
Debt Instruments [Abstract]
Total facility	4,400,000,000		4,400,000,000
Amount available	$ 3,100,000,000		$ 3,100,000,000
Number of lenders | lender	23		23
Share of facility held by lenders (as a percent)	6.00%		6.00%
Allowed increase in letters of credit	$ 500,000,000		$ 500,000,000
Letters of credit outstanding	$ 0		$ 0
Ratio of indebtedness to total capitalization (as a percent)	65.00%		65.00%
Sempra Energy | Parent Company | Letter of Credit
Debt Instruments [Abstract]
Long-term debt outstanding	$ 200,000,000		$ 200,000,000
Sempra Energy | Parent Company | Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instruments [Abstract]
Proceeds from issuance of debt	$ 2,350,000,000
LIBOR | Parent Company | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Stated percentage rate	2.50%		2.50%
LIBOR | Parent Company | 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instruments [Abstract]
Variable percentage rate		2.868%
LIBOR | Sempra Energy | Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Stated percentage rate					2.50%

Uncategorized Items - sre-20211

Label	Element	Value
Southern California Gas Company [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]
Accounting Standards Update 2016-02 [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2016-02 [Member]
Accounting Standards Update 2018-02 [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]
Accounting Standards Update 2018-02 [Member] | San Diego Gas and Electric Company [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]