Southern California Gas Company PFD 6% (SOCGM) 10-Q3 Aug 232023 Q2 Quarterly reportFinancial data

Company Profile

COVER

COVER - shares	6 Months Ended
COVER - shares	Jun. 30, 2023	Jul. 31, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		314,653,565
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company
Document 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	8330 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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000086521
Southern California Gas Company
Document 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 5th 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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000092108
Common stock
Document 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
Document 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

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
REVENUES
Natural gas	$ 1,660	$ 1,704	$ 6,072	$ 4,024
Electric	1,054	1,189	2,081	2,306
Energy-related businesses	621	654	1,742	1,037
Total revenues	3,335	3,547	9,895	7,367
Operating expenses:
Operation and maintenance	(1,366)	(1,162)	(2,575)	(2,248)
Aliso Canyon litigation and regulatory matters	0	(45)	0	(137)
Depreciation and amortization	(549)	(501)	(1,088)	(994)
Franchise fees and other taxes	(148)	(150)	(340)	(312)
Other income (expense), net	31	(1)	72	37
Interest income	17	15	41	40
Interest expense	(317)	(271)	(683)	(514)
Income before income taxes and equity earnings	523	364	1,852	1,029
Income Tax Expense	(175)	(80)	(551)	(414)
Equity earnings	388	375	607	701
Net income	736	659	1,908	1,316
Earnings attributable to noncontrolling interests	(121)	(88)	(313)	(122)
Preferred dividends	(11)	(11)	(22)	(22)
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Earnings attributable to common shares	$ 603	$ 559	$ 1,572	$ 1,171
Basic EPS:
Earnings (in dollars per share)	$ 1.91	$ 1.78	$ 4.99	$ 3.71
Weighted-average common shares outstanding (in shares)	315,007	314,845	314,963	315,595
Diluted EPS:
Earnings (in dollars per share)	$ 1.91	$ 1.77	$ 4.97	$ 3.70
Weighted-average common shares outstanding (in shares)	316,060	315,867	316,092	316,647
Natural gas
Operating expenses:
Operating expenses	$ (311)	$ (528)	$ (2,994)	$ (1,330)
Electric fuel and purchased power
Operating expenses:
Operating expenses	(88)	(251)	(202)	(456)
Energy-related businesses
Operating expenses:
Operating expenses	$ (81)	$ (289)	$ (274)	$ (424)

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net income	$ 736	$ 659	$ 1,908	$ 1,316
Other comprehensive income (loss):
Foreign currency translation adjustments	15	2	29	6
Financial instruments	101	63	6	161
Pension and other postretirement benefits	1	3	(11)	11
Total other comprehensive income	117	68	24	178
Comprehensive income	853	727	1,932	1,494
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income	852	726	1,931	1,493
Pretax amount
Net income	790	651	2,146	1,608
Other comprehensive income (loss):
Foreign currency translation adjustments	11	2	21	5
Financial instruments	69	65	8	167
Pension and other postretirement benefits	2	4	(10)	13
Total other comprehensive income	82	71	19	185
Comprehensive income	872	722	2,165	1,793
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income	871	721	2,164	1,792
Income tax (expense) benefit
Net income	(175)	(80)	(551)	(414)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0	0
Financial instruments	(20)	(17)	(4)	(41)
Pension and other postretirement benefits	(1)	(1)	(1)	(2)
Total other comprehensive income	(21)	(18)	(5)	(43)
Comprehensive income	(196)	(98)	(556)	(457)
Preferred dividends of subsidiary	0	0	0	0
Comprehensive income	(196)	(98)	(556)	(457)
Net-of-tax amount
Net income	615	571	1,595	1,194
Other comprehensive income (loss):
Foreign currency translation adjustments	11	2	21	5
Financial instruments	49	48	4	126
Pension and other postretirement benefits	1	3	(11)	11
Total other comprehensive income	61	53	14	142
Comprehensive income	676	624	1,609	1,336
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income	675	623	1,608	1,335
Noncontrolling interests (after tax)
Net income	121	88	313	122
Other comprehensive income (loss):
Foreign currency translation adjustments	4	0	8	1
Financial instruments	52	15	2	35
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive income	56	15	10	36
Comprehensive income	177	103	323	158
Preferred dividends of subsidiary	0	0	0	0
Comprehensive income	$ 177	$ 103	$ 323	$ 158

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 1,077	$ 370	[1]
Restricted cash	74	40	[1]
Accounts receivable – trade, net	1,970	2,635	[1]
Accounts receivable – other, net	489	685	[1]
Due from unconsolidated affiliates	26	54	[1]
Income taxes receivable	74	113	[1]
Inventories	383	403	[1]
Prepaid expenses	159	268	[1]
Regulatory assets	105	351	[1]
Fixed-price contracts and other derivatives	256	803	[1]
Greenhouse gas allowances	143	141	[1]
Other current assets	91	49	[1]
Total current assets	4,847	5,912	[1]
Other assets:
Restricted cash	91	52	[1]
Regulatory assets	3,227	2,588	[1]
Greenhouse gas allowances	1,045	796	[1]
Nuclear decommissioning trusts	863	841	[1]
Dedicated assets in support of certain benefit plans	520	505	[1]
Deferred income taxes	149	135	[1]
Right-of-use assets – operating leases	722	655	[1]
Investment in Oncor Holdings	13,869	13,665	[1]
Other investments	2,146	2,012	[1]
Goodwill	1,602	1,602	[1]
Other intangible assets	331	344	[1]
Wildfire fund	288	303	[1]
Other long-term assets	1,549	1,382	[1]
Total other assets	26,402	24,880	[1]
Property, plant and equipment:
Property, plant and equipment	68,270	63,893	[1]
Less accumulated depreciation and amortization	(16,792)	(16,111)	[1]
Property, plant and equipment, net	51,478	47,782	[1]
Total assets	82,727	78,574	[1]
Current liabilities:
Short-term debt	2,512	3,352	[1]
Accounts payable – trade	1,790	1,994	[1]
Accounts payable – other	234	275	[1]
Dividends and interest payable	651	621	[1]
Accrued compensation and benefits	364	484	[1]
Regulatory liabilities	650	504	[1]
Current portion of long-term debt and finance leases	924	1,019	[1]
Reserve for Aliso Canyon costs	126	129	[1]
Greenhouse gas obligations	143	141	[1]
Total current liabilities	8,451	9,899	[1]
Long-term debt and finance leases	27,521	24,548	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	282	301	[1]
Regulatory liabilities	3,435	3,341	[1]
Greenhouse gas obligations	800	565	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	346	410	[1]
Deferred income taxes	5,064	4,591	[1]
Asset retirement obligations	3,536	3,546	[1]
Deferred credits and other	2,278	2,117	[1]
Total deferred credits and other liabilities	15,741	14,871	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,044	12,160	[1]
Retained earnings	15,024	14,201	[1]
Accumulated other comprehensive income (loss)	(121)	(135)	[1]
Total shareholders’ equity	27,836	27,115	[1]
Preferred stock of subsidiary	20	20	[1]
Other noncontrolling interests	3,158	2,121	[1]
Total equity	31,014	29,256	[1]
Total liabilities and equity	82,727	78,574	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	26	54
Current liabilities:
Other current liabilities	5	0	[1]
Nonrelated Party
Current liabilities:
Other current liabilities	1,052	1,380	[1]
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	[1]

[1]Derived from audited financial statements.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Jun. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,908	$ 1,316
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,088	994
Deferred income taxes and investment tax credits	323	379
Equity earnings	(607)	(701)
Foreign currency transaction (gains) losses, net	(4)	22
Share-based compensation expense	31	32
Fixed-price contracts and other derivatives	(569)	122
Other	205	101
Net change in working capital components	1,474	(3)
Insurance receivable for Aliso Canyon costs	0	16
Distributions from investments	402	403
Changes in other noncurrent assets and liabilities, net	(514)	(317)
Net cash provided by operating activities	3,737	2,364
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(4,282)	(2,361)
Expenditures for investments	(184)	(181)
Purchases of nuclear decommissioning and other trust assets	(322)	(397)
Proceeds from sales of nuclear decommissioning and other trust assets	356	397
Other	11	7
Net cash used in investing activities	(4,421)	(2,535)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(734)	(711)
Preferred dividends paid	(22)	(22)
Issuances of common stock	0	3
Repurchases of common stock	(31)	(476)
Issuances of debt (maturities greater than 90 days)	5,614	4,818
Payments on debt (maturities greater than 90 days) and finance leases	(3,392)	(1,543)
Decrease in short-term debt, net	(388)	(2,011)
Advances from unconsolidated affiliates	14	18
Proceeds from sales of noncontrolling interests	265	1,732
Distributions to noncontrolling interests	(252)	(106)
Contributions from noncontrolling interests	543	13
Settlement of cross-currency swaps	(99)	0
Other	(61)	(30)
Net cash provided by financing activities	1,457	1,685
Effect of exchange rate changes on cash, cash equivalents and restricted cash	7	(2)
Increase in cash, cash equivalents and restricted cash	780	1,512
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, June 30	1,242	2,093
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	612	466
Income tax payments, net of refunds	120	233
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Repayment of advances from unconsolidated affiliate in lieu of distribution	36	32
Accrued capital expenditures	863	476
Contributions from NCI	186	0
Increase in finance lease obligations for investment in PP&E	36	22
(Decrease) increase in ARO for investment in PP&E	(46)	55
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	11	11
Common stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	$ 375	$ 359

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series C Preferred Stock	Preferred stock	Common stock	Retained earnings	Retained earnings Series C Preferred Stock	Accumulated other comprehensive income (loss)	Sempra shareholders' equity	Sempra shareholders' equity Series C Preferred Stock	Non- controlling interests
Beginning Balance at Dec. 31, 2021	$ 27,419			$ 889	$ 11,862	$ 13,548		$ (318)	$ 25,981		$ 1,438
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,316					1,194			1,194		122
Other comprehensive (loss) income	178							142	142		36
Share-based compensation expense	32				32				32
Dividends declared:
Preferred dividends			$ (22)				$ (22)			$ (22)
Common stock dividends declared	(721)					(721)			(721)
Preferred dividends of subsidiary	(1)					(1)			(1)
Issuances of common stock	3				3				3
Repurchases of common stock	(476)				(476)				(476)
Noncontrolling interest activities:
Contributions	13										13
Distributions	(106)										(106)
Sale	1,418				700			9	709		709
Ending balance at Jun. 30, 2022	29,053			889	12,121	13,998		(167)	26,841		2,212
Beginning Balance at Mar. 31, 2022	27,560			889	11,656	13,798		(229)	26,114		1,446
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	659					571			571		88
Other comprehensive (loss) income	68							53	53		15
Share-based compensation expense	15				15				15
Dividends declared:
Preferred dividends			(11)				(11)			(11)
Common stock dividends declared	(359)					(359)			(359)
Preferred dividends of subsidiary	(1)					(1)			(1)
Repurchases of common stock	(250)				(250)				(250)
Noncontrolling interest activities:
Contributions	7										7
Distributions	(53)										(53)
Sale	1,418				700			9	709		709
Ending balance at Jun. 30, 2022	29,053			889	12,121	13,998		(167)	26,841		2,212
Beginning Balance at Dec. 31, 2022	29,256	[1]		889	12,160	14,201		(135)	27,115		2,141
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,908					1,595			1,595		313
Other comprehensive (loss) income	24							14	14		10
Share-based compensation expense	31				31				31
Dividends declared:
Preferred dividends			(22)				(22)			(22)
Common stock dividends declared	(749)					(749)			(749)
Preferred dividends of subsidiary	(1)					(1)			(1)
Repurchases of common stock	(31)				(31)				(31)
Noncontrolling interest activities:
Contributions	595				(134)				(134)		729
Distributions	(252)										(252)
Sale	255				18				18		237
Ending balance at Jun. 30, 2023	31,014			889	12,044	15,024		(121)	27,836		3,178
Beginning Balance at Mar. 31, 2023	30,245			889	12,164	14,796		(182)	27,667		2,578
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	736					615			615		121
Other comprehensive (loss) income	117							61	61		56
Share-based compensation expense	14				14				14
Dividends declared:
Preferred dividends			$ (11)				$ (11)			$ (11)
Common stock dividends declared	(375)					(375)			(375)
Preferred dividends of subsidiary	(1)					(1)			(1)
Noncontrolling interest activities:
Contributions	498				(134)				(134)		632
Distributions	(209)										(209)
Ending balance at Jun. 30, 2023	$ 31,014			$ 889	$ 12,044	$ 15,024		$ (121)	$ 27,836		$ 3,178

[1]Derived from audited financial statements.

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Dividends declared per share of common stock (in dollars per share)	$ 1.19	$ 1.14	$ 2.38	$ 2.29
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19	$ 24.38	$ 24.38

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
REVENUES
Electric	$ 1,054	$ 1,189	$ 2,081	$ 2,306
Natural gas	1,660	1,704	6,072	4,024
Operating expenses:
Other Income, Net	31	(1)	72	37
Interest income	17	15	41	40
Interest expense	(317)	(271)	(683)	(514)
Income before income taxes and equity earnings	523	364	1,852	1,029
Income Tax Expense	(175)	(80)	(551)	(414)
Net income	736	659	1,908	1,316
Earnings attributable to common shares	603	559	1,572	1,171
San Diego Gas and Electric Company
REVENUES
Electric	1,058	1,192	2,089	2,312
Natural gas	204	207	826	532
Operating revenues	1,262	1,399	2,915	2,844
Operating expenses:
Cost of electric fuel and purchased power	107	269	242	490
Cost of natural gas	38	69	417	195
Operation and maintenance	474	420	901	817
Depreciation and amortization	268	244	530	483
Franchise fees and other taxes	90	88	186	180
Total operating expenses	977	1,090	2,276	2,165
Operating income	285	309	639	679
Other Income, Net	22	22	50	56
Interest income	4	1	5	1
Interest expense	(123)	(114)	(241)	(220)
Income before income taxes and equity earnings	188	218	453	516
Income Tax Expense	(4)	(42)	(11)	(106)
Net income	184	176	442	410
Earnings attributable to common shares	$ 184	$ 176	$ 442	$ 410

CONDENSED STATEMENTS OF COMPREH

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net income	$ 736	$ 659	$ 1,908	$ 1,316
Comprehensive income	852	726	1,931	1,493
Pretax amount
Net income	790	651	2,146	1,608
Comprehensive income	871	721	2,164	1,792
Income tax (expense) benefit
Net income	(175)	(80)	(551)	(414)
Comprehensive income	(196)	(98)	(556)	(457)
Net-of-tax amount
Net income	615	571	1,595	1,194
Comprehensive income	675	623	1,608	1,335
San Diego Gas and Electric Company
Net income	184	176	442	410
San Diego Gas and Electric Company \| Pretax amount
Net income	188	218	453	516
Comprehensive income	188	218	453	516
San Diego Gas and Electric Company \| Income tax (expense) benefit
Net income	(4)	(42)	(11)	(106)
Comprehensive income	(4)	(42)	(11)	(106)
San Diego Gas and Electric Company \| Net-of-tax amount
Net income	184	176	442	410
Comprehensive income	$ 184	$ 176	$ 442	$ 410

CONDENSED BALANCE SHEETS - SDG&

CONDENSED BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 1,077	$ 370	[1]
Accounts receivable – trade, net	1,970	2,635	[1]
Accounts receivable – other, net	489	685	[1]
Due from unconsolidated affiliates	26	54	[1]
Inventories	383	403	[1]
Prepaid expenses	159	268	[1]
Regulatory assets	105	351	[1]
Fixed-price contracts and other derivatives	256	803	[1]
Greenhouse gas allowances	143	141	[1]
Other current assets	91	49	[1]
Total current assets	4,847	5,912	[1]
Other assets:
Regulatory assets	3,227	2,588	[1]
Greenhouse gas allowances	1,045	796	[1]
Nuclear decommissioning trusts	863	841	[1]
Right-of-use assets – operating leases	722	655	[1]
Wildfire fund	288	303	[1]
Other long-term assets	1,549	1,382	[1]
Total other assets	26,402	24,880	[1]
Property, plant and equipment:
Property, plant and equipment	68,270	63,893	[1]
Less accumulated depreciation and amortization	(16,792)	(16,111)	[1]
Property, plant and equipment, net	51,478	47,782	[1]
Total assets	82,727	78,574	[1]
Current liabilities:
Short-term debt	2,512	3,352	[1]
Accrued compensation and benefits	364	484	[1]
Regulatory liabilities	650	504	[1]
Current portion of long-term debt and finance leases	924	1,019	[1]
Greenhouse gas obligations	143	141	[1]
Total current liabilities	8,451	9,899	[1]
Long-term debt and finance leases	27,521	24,548	[1]
Deferred credits and other liabilities:
Regulatory liabilities	3,435	3,341	[1]
Greenhouse gas obligations	800	565	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	346	410	[1]
Deferred income taxes	5,064	4,591	[1]
Asset retirement obligations	3,536	3,546	[1]
Deferred credits and other	2,278	2,117	[1]
Total deferred credits and other liabilities	15,741	14,871	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,044	12,160	[1]
Retained earnings	15,024	14,201	[1]
Accumulated other comprehensive income (loss)	(121)	(135)	[1]
Total shareholders’ equity	27,836	27,115	[1]
Total liabilities and equity	82,727	78,574	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	26	54
Current liabilities:
Other current liabilities	5	0	[1]
Nonrelated Party
Current liabilities:
Other current liabilities	1,052	1,380	[1]
San Diego Gas and Electric Company
Current assets:
Cash and cash equivalents	332	7	[1]
Accounts receivable – trade, net	813	799	[1]
Accounts receivable – other, net	149	110	[1]
Due from unconsolidated affiliates	1	0	[1]
Inventories	143	134	[1]
Prepaid expenses	78	179	[1]
Regulatory assets	39	247	[1]
Fixed-price contracts and other derivatives	76	113	[1]
Greenhouse gas allowances	22	22	[1]
Other current assets	25	19	[1]
Total current assets	1,678	1,630	[1]
Other assets:
Regulatory assets	1,564	1,219	[1]
Greenhouse gas allowances	230	196	[1]
Nuclear decommissioning trusts	863	841	[1]
Right-of-use assets – operating leases	364	281	[1]
Wildfire fund	288	303	[1]
Other long-term assets	136	146	[1]
Total other assets	3,445	2,986	[1]
Property, plant and equipment:
Property, plant and equipment	29,704	28,574	[1]
Less accumulated depreciation and amortization	(7,041)	(6,768)	[1]
Property, plant and equipment, net	22,663	21,806	[1]
Total assets	27,786	26,422	[1]
Current liabilities:
Short-term debt	0	205	[1]
Accounts payable	757	744	[1]
Interest payable	77	63	[1]
Accrued compensation and benefits	95	140	[1]
Accrued franchise fees	77	120	[1]
Regulatory liabilities	232	110	[1]
Current portion of long-term debt and finance leases	891	489	[1]
Greenhouse gas obligations	22	22	[1]
Asset retirement obligations	107	98	[1]
Total current liabilities	2,572	2,319	[1]
Long-term debt and finance leases	8,865	8,497	[1]
Deferred credits and other liabilities:
Regulatory liabilities	2,406	2,298	[1]
Greenhouse gas obligations	119	81	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	33	42	[1]
Deferred income taxes	2,576	2,540	[1]
Asset retirement obligations	779	789	[1]
Deferred credits and other	927	789	[1]
Total deferred credits and other liabilities	6,840	6,539	[1]
Commitments and contingencies			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,660	1,660	[1]
Retained earnings	7,856	7,414	[1]
Accumulated other comprehensive income (loss)	(7)	(7)	[1]
Total shareholders’ equity	9,509	9,067	[1]
Total liabilities and equity	27,786	26,422	[1]
San Diego Gas and Electric Company \| Related Party
Current assets:
Due from unconsolidated affiliates	1	0
Current liabilities:
Other current liabilities	43	135	[1]
San Diego Gas and Electric Company \| Nonrelated Party
Current liabilities:
Other current liabilities	$ 271	$ 193	[1]

[1]Derived from audited financial statements.

CONDENSED BALANCE SHEETS - SD_2

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Jun. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
San Diego Gas and Electric Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	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
Common stock, shares outstanding (in shares)	117,000,000	117,000,000

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,908	$ 1,316
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,088	994
Deferred income taxes and investment tax credits	323	379
Other	205	101
Net change in working capital components	1,474	(3)
Changes in other noncurrent assets and liabilities, net	(514)	(317)
Net cash provided by operating activities	3,737	2,364
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(4,282)	(2,361)
Purchases of nuclear decommissioning and other trust assets	(322)	(397)
Proceeds from sales of nuclear decommissioning and other trust assets	356	397
Other	11	7
Net cash used in investing activities	(4,421)	(2,535)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	5,614	4,818
Payments on debt (maturities greater than 90 days) and finance leases	(3,392)	(1,543)
Increase (decrease) in short-term debt, net	(388)	(2,011)
Net cash provided by financing activities	1,457	1,685
Increase in cash, cash equivalents and restricted cash	780	1,512
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, June 30	1,242	2,093
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	612	466
Income tax payments, net of refunds	120	233
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	863	476
Increase in finance lease obligations for investment in PP&E	36	22
San Diego Gas and Electric Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	442	410
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	530	483
Deferred income taxes and investment tax credits	(31)	41
Other	31	19
Net change in working capital components	235	165
Changes in other noncurrent assets and liabilities, net	(241)	(105)
Net cash provided by operating activities	966	1,013
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,239)	(1,090)
Purchases of nuclear decommissioning and other trust assets	(265)	(397)
Proceeds from sales of nuclear decommissioning and other trust assets	294	397
Other	10	8
Net cash used in investing activities	(1,200)	(1,082)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	792	1,395
Payments on debt (maturities greater than 90 days) and finance leases	(19)	(408)
Increase (decrease) in short-term debt, net	(205)	(401)
Debt issuance costs	(9)	(9)
Net cash provided by financing activities	559	577
Increase in cash, cash equivalents and restricted cash	325	508
Cash, cash equivalents and restricted cash, January 1	7	25
Cash, cash equivalents and restricted cash, June 30	332	533
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	224	206
Income tax payments, net of refunds	0	68
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	233	186
Increase in ARO for investment in PP&E	10	1
Increase in finance lease obligations for investment in PP&E	$ 4	$ 9

CONDENSED STATEMENTS OF CHANGES

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E - USD ($) $ in Millions	Total		Common stock	Retained earnings	Accumulated other comprehensive income (loss)	San Diego Gas and Electric Company	San Diego Gas and Electric Company Common stock	San Diego Gas and Electric Company Retained earnings	San Diego Gas and Electric Company Accumulated other comprehensive income (loss)
Beginning Balance at Dec. 31, 2021	$ 27,419		$ 11,862	$ 13,548	$ (318)	$ 8,249	$ 1,660	$ 6,599	$ (10)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,316			1,194		410		410
Ending balance at Jun. 30, 2022	29,053		12,121	13,998	(167)	8,659	1,660	7,009	(10)
Beginning Balance at Mar. 31, 2022	27,560		11,656	13,798	(229)	8,483	1,660	6,833	(10)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	659			571		176		176
Ending balance at Jun. 30, 2022	29,053		12,121	13,998	(167)	8,659	1,660	7,009	(10)
Beginning Balance at Dec. 31, 2022	29,256	[1]	12,160	14,201	(135)	9,067	1,660	7,414	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,908			1,595		442		442
Ending balance at Jun. 30, 2023	31,014		12,044	15,024	(121)	9,509	1,660	7,856	(7)
Beginning Balance at Mar. 31, 2023	30,245		12,164	14,796	(182)	9,325	1,660	7,672	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	736			615		184		184
Ending balance at Jun. 30, 2023	$ 31,014		$ 12,044	$ 15,024	$ (121)	$ 9,509	$ 1,660	$ 7,856	$ (7)

[1]Derived from audited financial statements.

CONDENSED STATEMENTS OF OPERA_2

CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating expenses:
Aliso Canyon litigation and regulatory matters	$ 0	$ 45	$ 0	$ 137
Other income (expense), net	31	(1)	72	37
Interest income	17	15	41	40
Interest expense	(317)	(271)	(683)	(514)
Income before income taxes and equity earnings	523	364	1,852	1,029
Income tax benefit (expense)	(175)	(80)	(551)	(414)
Net income	736	659	1,908	1,316
Preferred dividends	(11)	(11)	(22)	(22)
Earnings attributable to common shares	603	559	1,572	1,171
Southern California Gas Company
REVENUES
Operating revenues	1,467	1,501	5,261	3,494
Operating expenses:
Cost of natural gas	284	459	2,631	1,136
Operation and maintenance	715	605	1,340	1,156
Aliso Canyon litigation and regulatory matters	0	45	0	137
Depreciation and amortization	208	188	414	375
Franchise fees and other taxes	56	57	145	119
Total operating expenses	1,263	1,354	4,530	2,923
Operating income	204	147	731	571
Other income (expense), net	1	4	(7)	38
Interest income	1	1	5	1
Interest expense	(71)	(45)	(140)	(85)
Income before income taxes and equity earnings	135	107	589	525
Income tax benefit (expense)	21	(19)	(73)	(103)
Net income	156	88	516	422
Preferred dividends	(1)	(1)	(1)	(1)
Earnings attributable to common shares	$ 155	$ 87	$ 515	$ 421

CONDENSED STATEMENTS OF COMPR_2

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SoCalGas - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net income	$ 736	$ 659	$ 1,908	$ 1,316
Other comprehensive income (loss):
Financial instruments	101	63	6	161
Pension and other postretirement benefits	1	3	(11)	11
Total other comprehensive income	117	68	24	178
Comprehensive income	852	726	1,931	1,493
Pretax amount
Net income	790	651	2,146	1,608
Other comprehensive income (loss):
Financial instruments	69	65	8	167
Pension and other postretirement benefits	2	4	(10)	13
Total other comprehensive income	82	71	19	185
Comprehensive income	871	721	2,164	1,792
Income tax (expense) benefit
Net income	(175)	(80)	(551)	(414)
Other comprehensive income (loss):
Financial instruments	(20)	(17)	(4)	(41)
Pension and other postretirement benefits	(1)	(1)	(1)	(2)
Total other comprehensive income	(21)	(18)	(5)	(43)
Comprehensive income	(196)	(98)	(556)	(457)
Net-of-tax amount
Net income	615	571	1,595	1,194
Other comprehensive income (loss):
Financial instruments	49	48	4	126
Pension and other postretirement benefits	1	3	(11)	11
Total other comprehensive income	61	53	14	142
Comprehensive income	675	623	1,608	1,335
Southern California Gas Company
Net income	156	88	516	422
Other comprehensive income (loss):
Total other comprehensive income	1	1	2	2
Southern California Gas Company \| Pretax amount
Net income	135	107	589	525
Other comprehensive income (loss):
Financial instruments	1	1	1	1
Pension and other postretirement benefits			1	1
Total other comprehensive income	1	1	2	2
Comprehensive income	136	108	591	527
Southern California Gas Company \| Income tax (expense) benefit
Net income	21	(19)	(73)	(103)
Other comprehensive income (loss):
Financial instruments	0	0	0	0
Pension and other postretirement benefits			0	0
Total other comprehensive income	0	0	0	0
Comprehensive income	21	(19)	(73)	(103)
Southern California Gas Company \| Net-of-tax amount
Net income	156	88	516	422
Other comprehensive income (loss):
Financial instruments	1	1	1	1
Pension and other postretirement benefits			1	1
Total other comprehensive income	1	1	2	2
Comprehensive income	$ 157	$ 89	$ 518	$ 424

CONDENSED BALANCE SHEETS - SoCa

CONDENSED BALANCE SHEETS - SoCalGas - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 1,077	$ 370	[1]
Accounts receivable – trade, net	1,970	2,635	[1]
Accounts receivable – other, net	489	685	[1]
Due from unconsolidated affiliates	26	54	[1]
Inventories	383	403	[1]
Regulatory assets	105	351	[1]
Greenhouse gas allowances	143	141	[1]
Other current assets	91	49	[1]
Total current assets	4,847	5,912	[1]
Other assets:
Regulatory assets	3,227	2,588	[1]
Greenhouse gas allowances	1,045	796	[1]
Right-of-use assets – operating leases	722	655	[1]
Other long-term assets	1,549	1,382	[1]
Total other assets	26,402	24,880	[1]
Property, plant and equipment:
Property, plant and equipment	68,270	63,893	[1]
Less accumulated depreciation and amortization	(16,792)	(16,111)	[1]
Property, plant and equipment, net	51,478	47,782	[1]
Total assets	82,727	78,574	[1]
Current liabilities:
Short-term debt	2,512	3,352	[1]
Accounts payable – trade	1,790	1,994	[1]
Accounts payable – other	234	275	[1]
Accrued compensation and benefits	364	484	[1]
Regulatory liabilities	650	504	[1]
Current portion of long-term debt and finance leases	924	1,019	[1]
Reserve for Aliso Canyon costs	126	129	[1]
Greenhouse gas obligations	143	141	[1]
Total current liabilities	8,451	9,899	[1]
Long-term debt and finance leases	27,521	24,548	[1]
Deferred credits and other liabilities:
Regulatory liabilities	3,435	3,341	[1]
Greenhouse gas obligations	800	565	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	346	410	[1]
Deferred income taxes	5,064	4,591	[1]
Asset retirement obligations	3,536	3,546	[1]
Deferred credits and other	2,278	2,117	[1]
Total deferred credits and other liabilities	15,741	14,871	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,044	12,160	[1]
Retained earnings	15,024	14,201	[1]
Accumulated other comprehensive income (loss)	(121)	(135)	[1]
Total shareholders’ equity	27,836	27,115	[1]
Total liabilities and equity	82,727	78,574	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	26	54
Current liabilities:
Other current liabilities	5	0	[1]
Nonrelated Party
Current liabilities:
Other current liabilities	1,052	1,380	[1]
Southern California Gas Company
Current assets:
Cash and cash equivalents	1	21	[1]
Accounts receivable – trade, net	856	1,295	[1]
Accounts receivable – other, net	84	293	[1]
Due from unconsolidated affiliates	1	77	[1]
Inventories	180	159	[1]
Regulatory assets	61	104	[1]
Greenhouse gas allowances	113	111	[1]
Other current assets	42	69	[1]
Total current assets	1,338	2,129	[1]
Other assets:
Regulatory assets	1,585	1,291	[1]
Greenhouse gas allowances	729	551	[1]
Right-of-use assets – operating leases	35	42	[1]
Other long-term assets	605	583	[1]
Total other assets	2,954	2,467	[1]
Property, plant and equipment:
Property, plant and equipment	25,872	25,058	[1]
Less accumulated depreciation and amortization	(7,573)	(7,308)	[1]
Property, plant and equipment, net	18,299	17,750	[1]
Total assets	22,591	22,346	[1]
Current liabilities:
Short-term debt	238	900	[1]
Accounts payable – trade	509	953	[1]
Accounts payable – other	161	176	[1]
Accrued compensation and benefits	170	209	[1]
Regulatory liabilities	418	394	[1]
Current portion of long-term debt and finance leases	22	318	[1]
Reserve for Aliso Canyon costs	126	129	[1]
Greenhouse gas obligations	113	111	[1]
Asset retirement obligations	66	68	[1]
Total current liabilities	2,171	3,723	[1]
Long-term debt and finance leases	6,790	5,780	[1]
Deferred credits and other liabilities:
Regulatory liabilities	1,029	1,043	[1]
Greenhouse gas obligations	630	443	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	225	277	[1]
Deferred income taxes	1,466	1,306	[1]
Asset retirement obligations	2,672	2,675	[1]
Deferred credits and other	393	401	[1]
Total deferred credits and other liabilities	6,415	6,145	[1]
Commitments and contingencies			[1]
Equity:
Preferred stock	22	22	[1]
Common stock	2,316	2,316	[1]
Retained earnings	4,899	4,384	[1]
Accumulated other comprehensive income (loss)	(22)	(24)	[1]
Total shareholders’ equity	7,215	6,698	[1]
Total liabilities and equity	22,591	22,346	[1]
Southern California Gas Company \| Related Party
Current assets:
Due from unconsolidated affiliates	1	77
Current liabilities:
Other current liabilities	36	36	[1]
Southern California Gas Company \| Nonrelated Party
Current liabilities:
Other current liabilities	$ 312	$ 429	[1]

[1]Derived from audited financial statements.

CONDENSED BALANCE SHEETS - So_2

CONDENSED BALANCE SHEETS - SoCalGas (Parentheticals) - shares	Jun. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
Southern California Gas Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	1,000,000	1,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,000,000	91,000,000

CONDENSED STATEMENTS OF CASH _2

CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,908	$ 1,316
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,088	994
Deferred income taxes and investment tax credits	323	379
Other	205	101
Net change in working capital components	1,474	(3)
Insurance receivable for Aliso Canyon costs	0	16
Changes in other noncurrent assets and liabilities, net	(514)	(317)
Net cash provided by operating activities	3,737	2,364
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(4,282)	(2,361)
Net cash used in investing activities	(4,421)	(2,535)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(22)	(22)
Issuances of debt (maturities greater than 90 days)	5,614	4,818
Payments on debt (maturities greater than 90 days) and finance leases	(3,392)	(1,543)
Increase (decrease) in short-term debt, net	(388)	(2,011)
Net cash provided by financing activities	1,457	1,685
Increase in cash, cash equivalents and restricted cash	780	1,512
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, June 30	1,242	2,093
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	612	466
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	863	476
Increase in finance lease obligations for investment in PP&E	36	22
(Decrease) increase in ARO for investment in PP&E	(46)	55
Southern California Gas Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	516	422
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	414	375
Deferred income taxes and investment tax credits	79	103
Other	156	36
Net change in working capital components	40	225
Insurance receivable for Aliso Canyon costs	0	16
Changes in other noncurrent assets and liabilities, net	(280)	(316)
Net cash provided by operating activities	925	861
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(961)	(931)
Net cash used in investing activities	(961)	(931)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)	(1)
Equity contribution from Sempra	0	150
Issuances of debt (maturities greater than 90 days)	997	697
Payments on debt (maturities greater than 90 days) and finance leases	(1,109)	(6)
Increase (decrease) in short-term debt, net	138	(385)
Debt issuance costs	(9)	(6)
Net cash provided by financing activities	16	449
Increase in cash, cash equivalents and restricted cash	(20)	379
Cash, cash equivalents and restricted cash, January 1	21	37
Cash, cash equivalents and restricted cash, June 30	1	416
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	138	75
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	222	199
Increase in finance lease obligations for investment in PP&E	32	13
(Decrease) increase in ARO for investment in PP&E	$ (56)	$ 54

CONDENSED STATEMENTS OF CHANG_2

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas - USD ($) $ in Millions	Total		Preferred stock	Common stock	Retained earnings	Accumulated other comprehensive income (loss)	Southern California Gas Company	Southern California Gas Company Preferred stock	Southern California Gas Company Common stock	Southern California Gas Company Retained earnings	Southern California Gas Company Accumulated other comprehensive income (loss)
Beginning Balance at Dec. 31, 2021	$ 27,419		$ 889	$ 11,862	$ 13,548	$ (318)	$ 5,442	$ 22	$ 1,666	$ 3,785	$ (31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,316				1,194		422			422
Other comprehensive (loss) income	178					142	2				2
Dividends declared:
Preferred dividends							(1)			(1)
Equity contribution from Sempra							150		150
Ending balance at Jun. 30, 2022	29,053		889	12,121	13,998	(167)	6,015	22	1,816	4,206	(29)
Beginning Balance at Mar. 31, 2022	27,560		889	11,656	13,798	(229)	5,777	22	1,666	4,119	(30)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	659				571		88			88
Other comprehensive (loss) income	68					53	1				1
Dividends declared:
Preferred dividends							(1)			(1)
Equity contribution from Sempra							150		150
Ending balance at Jun. 30, 2022	29,053		889	12,121	13,998	(167)	6,015	22	1,816	4,206	(29)
Beginning Balance at Dec. 31, 2022	29,256	[1]	889	12,160	14,201	(135)	6,698	22	2,316	4,384	(24)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,908				1,595		516			516
Other comprehensive (loss) income	24					14	2				2
Dividends declared:
Preferred dividends							(1)			(1)
Ending balance at Jun. 30, 2023	31,014		889	12,044	15,024	(121)	7,215	22	2,316	4,899	(22)
Beginning Balance at Mar. 31, 2023	30,245		889	12,164	14,796	(182)	7,059	22	2,316	4,744	(23)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	736				615		156			156
Other comprehensive (loss) income	117					61	1				1
Dividends declared:
Preferred dividends							(1)			(1)
Ending balance at Jun. 30, 2023	$ 31,014		$ 889	$ 12,044	$ 15,024	$ (121)	$ 7,215	$ 22	$ 2,316	$ 4,899	$ (22)

[1]Derived from audited financial statements.

CONDENSED STATEMENTS OF CHANG_3

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Southern California Gas Company
Dividends declared per share of preferred stock (in dollars per share)	$ 0.37	$ 0.37	$ 0.75	$ 0.75

GENERAL INFORMATION AND OTHER F

GENERAL INFORMATION AND OTHER FINANCIAL DATA	6 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GENERAL INFORMATION AND OTHER FINANCIAL DATA	GENERAL INFORMATION AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Effective May 12, 2023, our company changed its legal name from Sempra Energy to Sempra. Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities. We have four separate reportable segments, which we discuss in Note 11. 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 common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, 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. We have eliminated intercompany accounts and transactions within Sempra’s consolidated financial statements. We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2023 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. All December 31, 2022 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2022 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes. The information contained in this report should be read in conjunction with the Annual Report. Regulated Operations SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. 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 fully drawn against SEFE’s letters of credit, including draws associated with its LNG storage and regasification agreement; funds denominated in U.S. dollars and Mexican pesos to pay for rights-of-way and other costs pursuant to trust agreements related to pipeline projects; and certain funds at Port Arthur LNG for which withdrawals and usage are dictated by its debt agreements ▪ 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 Condensed Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Condensed Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) June 30, December 31, Cash and cash equivalents $ 1,077 $ 370 Restricted cash, current 74 40 Restricted cash, noncurrent 91 52 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 1,242 $ 462 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 sales-type leases 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 5. 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 the first quarter of 2022, SDG&E and SoCalGas received $63 million and $79 million, respectively, on behalf of their customers from the California Department of Community Services and Development under the 2021 California Arrearage Payment Program and applied the amounts directly to eligible customer accounts to reduce past due balances. In June 2022, AB 205 was approved establishing, among other things, the 2022 California Arrearage Payment Program. In December 2022, SDG&E and SoCalGas received funding of $51 million and $59 million, respectively, related to this program and, in January 2023, applied the amounts directly to eligible customer accounts to reduce past due balances. We provide below the 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. CHANGES IN ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) 2023 2022 Sempra: Allowances for credit losses at January 1 $ 181 $ 136 Provisions for expected credit losses 228 77 Write-offs (43) (36) Allowances for credit losses at June 30 $ 366 $ 177 SDG&E: Allowances for credit losses at January 1 $ 78 $ 66 Provisions for expected credit losses 63 37 Write-offs (23) (18) Allowances for credit losses at June 30 $ 118 $ 85 SoCalGas: Allowances for credit losses at January 1 $ 98 $ 69 Provisions for expected credit losses 164 37 Write-offs (20) (18) Allowances for credit losses at June 30 $ 242 $ 88 Allowances for credit losses related to trade receivables and other receivables are included in the Condensed Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) June 30, December 31, 2023 2022 Sempra: Accounts receivable – trade, net $ 320 $ 140 Accounts receivable – other, net 46 40 Other long-term assets — 1 Total allowances for credit losses $ 366 $ 181 SDG&E: Accounts receivable – trade, net $ 91 $ 52 Accounts receivable – other, net 27 25 Other long-term assets — 1 Total allowances for credit losses $ 118 $ 78 SoCalGas: Accounts receivable – trade, net $ 223 $ 83 Accounts receivable – other, net 19 15 Total allowances for credit losses $ 242 $ 98 As we discuss below in “Note Receivable,” we have an interest-bearing promissory note due from KKR Pinnacle. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on this note receivable, including compounded interest and unamortized transaction costs, based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At June 30, 2023 and December 31, 2022, $6 million and $7 million, respectively, of expected credit losses are included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheets. As we discuss in Note 5, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra Infrastructure from the SDSRA. On a quarterly basis, we evaluate credit losses and record liabilities for expected credit losses on this off-balance sheet arrangement based on external credit ratings, published default rate studies and the maturity date of the arrangement. At both June 30, 2023 and December 31, 2022, $6 million of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets. INVENTORIES The components of inventories are as follows: INVENTORY BALANCES (Dollars in millions) Sempra SDG&E SoCalGas June 30, December 31, June 30, December 31, June 30, December 31, Natural gas $ 87 $ 106 $ 1 $ 1 $ 63 $ 74 LNG 17 62 — — — — Materials and supplies 279 235 142 133 117 85 Total $ 383 $ 403 $ 143 $ 134 $ 180 $ 159 NOTE RECEIVABLE In November 2021, Sempra loaned $300 million to KKR Pinnacle in exchange for an interest-bearing promissory note that is due in full no later than October 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 Pinnacle. At June 30, 2023 and December 31, 2022, Other Long-Term Assets includes $324 million and $316 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, on Sempra’s Condensed Consolidated Balance Sheets. CAPITALIZED FINANCING COSTS Capitalized financing costs include capitalized interest costs and AFUDC related to both debt and equity financing of construction projects. We capitalize interest costs incurred to finance capital projects and interest at equity method investments that have not commenced planned principal operations. The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sempra $ 110 $ 60 $ 183 $ 117 SDG&E 31 26 62 54 SoCalGas 20 17 35 35 PROPERTY, PLANT AND EQUIPMENT 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. Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the pipeline in the Yaqui territory that has made that section inoperable since August 2017. Discussions with the CFE regarding the future of the pipeline are underway and the parties are working on restarting service on the pipeline, including the potential re-routing of a portion of the pipeline. If the parties do not agree on a definitive arrangement to re-route a portion of the pipeline or the parties do not agree on a new service start date, Sempra Infrastructure retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. At June 30, 2023, Sempra Infrastructure had $414 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline. 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. We will continue to evaluate our VIEs for any changes that may impact our determination of whether an entity is a VIE and if we are the primary beneficiary. SDG&E SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various PPAs that include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and indirectly Sempra, is the primary beneficiary. SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements). SDG&E’s obligation to absorb natural gas costs may be a significant variable interest. In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based on our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which it considers the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If SDG&E determines that it is the primary beneficiary, SDG&E and Sempra consolidate the entity that owns the facility as a VIE. In addition to tolling agreements, other variable interests involve various elements of fuel and power costs, and other components of cash flows expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities, including the operation and maintenance activities of the generating facility, that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects could be significant to the financial position and liquidity of SDG&E and Sempra. SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at June 30, 2023 and December 31, 2022. PPAs and tolling agreements that relate to SDG&E’s involvement with VIEs are primarily accounted for as finance leases. The carrying amounts of the assets and liabilities under these contracts are included in PP&E, net, and finance lease liabilities with balances of $1,181 million and $1,194 million at June 30, 2023 and December 31, 2022, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant. Sempra Texas Utilities Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $13,869 million and $13,665 million at June 30, 2023 and December 31, 2022, respectively. Sempra Infrastructure Cameron LNG JV Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, including LNG production and operation and maintenance activities at the liquefaction facility. Therefore, we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment, including amounts recognized in AOCI related to interest-rate cash flow hedges at Cameron LNG JV, was $979 million at June 30, 2023 and $886 million at December 31, 2022. Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and our obligation under the SDSRA, which we discuss in Note 5. CFIN As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN, which is a VIE. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of CFIN, including modification, prepayment, and refinance decisions related to the financing arrangement with external lenders and Cameron LNG JV’s four project owners as well as the ability to determine and enforce remedies in the event of default. The conditional obligations of the Support Agreement represent a variable interest that we measure at fair value on a recurring basis (see Note 8). Sempra’s maximum exposure to loss under the terms of the Support Agreement is $979 million. ECA LNG Phase 1 ECA LNG Phase 1 is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that ECA LNG Phase 1 will require future capital contributions or other financial support to finance the construction of the facility. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $1,330 million and $1,099 million of assets at June 30, 2023 and December 31, 2022, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $900 million and $685 million of liabilities at June 30, 2023 and December 31, 2022, respectively, consisting primarily of long-term debt, accounts payable and short-term debt attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 6, IEnova and TotalEnergies SE have provided guarantees for 83.4% and 16.6%, respectively, of the loan facility supporting construction of the liquefaction facility. Port Arthur LNG Port Arthur LNG is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that Port Arthur LNG will require future capital contributions or other financial support to finance the construction of the PA LNG Phase 1 project. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate Port Arthur LNG. Sempra consolidated $2,690 million of assets at June 30, 2023 consisting primarily of PP&E, net, attributable to Port Arthur LNG that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $455 million of liabilities at June 30, 2023 consisting primarily of accounts payable and long-term debt attributable to Port Arthur LNG for which creditors do not have recourse to the general credit of Sempra. PENSION AND PBOP Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost. The components of net periodic benefit cost, other than the service cost component, are included in the Other Income (Expense), Net, table below. NET PERIODIC BENEFIT COST – SEMPRA (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 29 $ 42 $ 3 $ 6 Interest cost 39 29 10 7 Expected return on assets (42) (45) (18) (16) Amortization of: Prior service cost 1 2 — — Actuarial loss (gain) 2 5 (6) (3) Net periodic benefit cost (credit) 29 33 (11) (6) Regulatory adjustments 29 24 11 6 Total expense recognized $ 58 $ 57 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 57 $ 83 $ 7 $ 13 Interest cost 79 59 19 14 Expected return on assets (85) (91) (35) (32) Amortization of: Prior service cost (credit) 2 5 (1) (1) Actuarial loss (gain) 4 11 (12) (7) Net periodic benefit cost (credit) 57 67 (22) (13) Regulatory adjustments 58 (3) 22 13 Total expense recognized $ 115 $ 64 $ — $ — NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 8 $ 10 $ — $ 1 Interest cost 10 6 2 2 Expected return on assets (10) (11) (2) (3) Amortization of: Actuarial loss 1 1 — — Net periodic benefit cost 9 6 — — Regulatory adjustments 4 7 — — Total expense recognized $ 13 $ 13 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 16 $ 20 $ 1 $ 3 Interest cost 20 13 4 3 Expected return on assets (20) (22) (4) (5) Amortization of: Actuarial loss (gain) 2 1 (1) (1) Net periodic benefit cost 18 12 — — Regulatory adjustments 8 2 — — Total expense recognized $ 26 $ 14 $ — $ — NET PERIODIC BENEFIT COST – SOCALGAS (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 17 $ 28 $ 2 $ 5 Interest cost 26 21 7 6 Expected return on assets (31) (33) (15) (14) Amortization of: Prior service cost 1 2 — — Actuarial loss (gain) — 4 (5) (3) Net periodic benefit cost (credit) 13 22 (11) (6) Regulatory adjustments 25 17 11 6 Total expense recognized $ 38 $ 39 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 34 $ 56 $ 5 $ 10 Interest cost 51 41 14 11 Expected return on assets (60) (64) (30) (27) Amortization of: Prior service cost (credit) 2 4 (1) (1) Actuarial loss (gain) — 8 (10) (6) Net periodic benefit cost (credit) 27 45 (22) (13) Regulatory adjustments 50 (5) 22 13 Total expense recognized $ 77 $ 40 $ — $ — DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS 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 $520 million and $505 million at June 30, 2023 and December 31, 2022, respectively. SEMPRA EARNINGS PER COMMON SHARE Basic EPS is calculated by dividing earnings attributable to common shares 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) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 315,007 314,845 314,963 315,595 Dilutive effect of stock options and RSUs (2) 1,053 1,022 1,129 1,052 Weighted-average common shares outstanding for diluted EPS 316,060 315,867 316,092 316,647 EPS: Basic $ 1.91 $ 1.78 $ 4.99 $ 3.71 Diluted $ 1.91 $ 1.77 $ 4.97 $ 3.70 (1) Includes 355 and 399 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 358 and 403 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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 of the Notes to Consolidated Financial Statements in the Annual Report, 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 the three months and six months ended June 30, 2023 excludes 214,069 and 197,042 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and six months ended June 30, 2022 excludes 8,899 and 173,064 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future. Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Development Committee of Sempra’s board of directors granted 163,287 nonqualified stock options, 330,810 performance-based RSUs and 135,461 service-based RSUs in the six months ended June 30, 2023, primarily in January. We discuss share-based compensation plans and related awards and the terms and conditions of Sempra’s equity securities further in Notes 10, 13 and 14 of the Notes to Consolidated Financial Statements in the Annual Report. COMPREHENSIVE INCOME The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, after amounts attributable to NCI. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (Dollars in millions) Foreign Financial Pension Total Three months ended June 30, 2023 and 2022 Sempra: Balance at March 31, 2023 $ (49) $ (35) $ (98) $ (182) OCI before reclassifications 11 53 — 64 Amounts reclassified from AOCI — (4) 1 (3) Net OCI 11 49 1 61 Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) Balance at March 31, 2022 $ (76) $ (78) $ (75) $ (229) OCI before reclassifications 1 37 1 39 Amounts reclassified from AOCI (2) 10 11 2 23 Net OCI (2) 11 48 3 62 Balance at June 30, 2022 $ (65) $ (30) $ (72) $ (167) SDG&E: Balance at March 31, 2023 and June 30, 2023 $ (7) $ (7) Balance at March 31, 2022 and June 30, 2022 $ (10) $ (10) SoCalGas: Balance at March 31, 2023 $ (12) $ (11) $ (23) Amounts reclassified from AOCI 1 — 1 Net OCI 1 — 1 Balance at June 30, 2023 $ (11) $ (11) $ (22) Balance at March 31, 2022 $ (13) $ (17) $ (30) Amounts reclassified from AOCI 1 — 1 Net OCI 1 — 1 Balance at June 30, 2022 $ (12) $ (17) $ (29) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $9 of foreign currency translation adjustments associated with sale of NCI to ADIA, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss). CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (CONTINUED) (Dollars in millions) Foreign Financial Pension Total Six months ended June 30, 2023 and 2022 Sempra: Balance at December 31, 2022 $ (59) $ 10 $ (86) $ (135) OCI before reclassifications 21 13 (13) 21 Amounts reclassified from AOCI — (9) 2 (7) Net OCI 21 4 (11) 14 Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) Balance at December 31, 2021 $ (79) $ (156) $ (83) $ (318) OCI before reclassifications 4 111 7 122 Amounts reclassified from AOCI (2) 10 15 4 29 Net OCI (2) 14 126 11 151 Balance at June 30, 2022 $ (65) $ (30) $ (72) $ (167) SDG&E: Balance at December 31, 2022 and June 30, 2023 $ (7) $ (7) Balance at December 31, 2021 and June 30, 2022 $ (10) $ (10) SoCalGas: Balance at December 31, 2022 $ (12) $ (12) $ (24) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at June 30, 2023 $ (11) $ (11) $ (22) Balance at December 31, 2021 $ (13) $ (18) $ (31) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at June 30, 2022 $ (12) $ (17) $ (29) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $9 of foreign currency translation adjustments associated with sale of NCI to ADIA, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about AOCI Amounts reclassified Affected line item on Condensed Three months ended June 30, 2023 2022 Sempra: Foreign currency translation adjustments $ — $ 1 Operation and Maintenance Financial instruments: Interest rate instruments $ (14) $ 13 Equity Earnings (1) Foreign exchange instruments — (1) Revenues: Energy-Related Businesses 1 1 Other Income (Expense), Net Foreign exchange instruments 1 — Equity Earnings Interest rate and foreign exchange instruments (1) (1) Interest Expense Total, before income tax (13) 12 — (4) Income Tax Expense Total, net of income tax (13) 8 9 3 Earnings Attributable to Noncontrolling Interests Total, net of income tax and after NCI $ (4) $ 11 Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ 2 Other Income (Expense), Net Amortization of prior service cost — 1 Other Income (Expense), Net Total, before income tax 1 3 — (1) Income Tax Expense Total, net of income tax $ 1 $ 2 Total reclassifications for the period, net of income tax and after NCI $ (3) $ 14 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 Interest Expense Total reclassifications for the period, net of income tax $ 1 $ 1 (1) Equity earnings at our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED) (Dollars in millions) Details about AOCI Amounts reclassified Affected line item on Condensed Six months ended June 30, 2023 2022 Sempra: Foreign currency translation adjustments $ — $ 1 Operation and Maintenance Financial instruments: Interest rate instruments $ — $ (1) Interest Expense Interest rate instruments (21) 27 Equity Earnings (1) Foreign exchange instruments — (2) Revenues: Energy-Related Businesses 2 1 Other Income (Expense), Net Foreign exchange instruments 2 (1) Equity Earnings (1) Interest rate and foreign exchange instruments (1) (1) Interest Expense (6) (6) Other Income (Expense), Net Total, before income tax (24) 17 3 (5) Income Tax Expense Total, net of income tax (21) 12 12 3 Earnings Attributable to Noncontrolling Interests Total, net of income tax and after NCI $ (9) $ 15 Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ 4 Other Income (Expense), Net Amortiz

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	6 Months Ended
NEW ACCOUNTING STANDARDS	Jun. 30, 2023
Accounting Changes and Error Corrections [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDSThere are no recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures.

REVENUES

REVENUES	6 Months Ended
REVENUES	Jun. 30, 2023
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUES We discuss revenue recognition for revenues from contracts with customers and from sources other than contracts with customers in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report. 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 Consolidating adjustments and Parent Sempra Three months ended June 30, 2023 By major service line: Utilities $ 1,400 $ 1,291 $ 19 $ (34) $ 2,676 Energy-related businesses — — 235 (19) 216 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 By market: Gas $ 252 $ 1,291 $ 167 $ (30) $ 1,680 Electric 1,148 — 87 (23) 1,212 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 Utilities regulatory revenues (138) 176 — — 38 Other revenues — — 406 (1) 405 Total revenues $ 1,262 $ 1,467 $ 660 $ (54) $ 3,335 Six months ended June 30, 2023 By major service line: Utilities $ 3,165 $ 5,132 $ 49 $ (72) $ 8,274 Energy-related businesses — — 547 (40) 507 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 By market: Gas $ 806 $ 5,132 $ 371 $ (65) $ 6,244 Electric 2,359 — 225 (47) 2,537 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 Utilities regulatory revenues (250) 129 — — (121) Other revenues — — 1,260 (25) 1,235 Total revenues $ 2,915 $ 5,261 $ 1,856 $ (137) $ 9,895 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) SDG&E SoCalGas Sempra Infrastructure Consolidating adjustments and Parent Sempra Three months ended June 30, 2022 By major service line: Utilities $ 1,250 $ 1,347 $ 20 $ (27) $ 2,590 Energy-related businesses — — 457 (14) 443 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 By market: Gas $ 159 $ 1,347 $ 340 $ (19) $ 1,827 Electric 1,091 — 137 (22) 1,206 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 Utilities regulatory revenues 149 154 — — 303 Other revenues — — 212 (1) 211 Total revenues $ 1,399 $ 1,501 $ 689 $ (42) $ 3,547 Six months ended June 30, 2022 By major service line: Utilities $ 2,751 $ 3,259 $ 48 $ (56) $ 6,002 Energy-related businesses — — 749 (29) 720 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 By market: Gas $ 489 $ 3,259 $ 569 $ (45) $ 4,272 Electric 2,262 — 228 (40) 2,450 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 Utilities regulatory revenues 93 235 — — 328 Other revenues — — 316 1 317 Total revenues $ 2,844 $ 3,494 $ 1,113 $ (84) $ 7,367 REVENUES FROM CONTRACTS WITH CUSTOMERS Remaining Performance Obligations For contracts greater than one year, at June 30, 2023, 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 and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2023. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2023 (excluding first six months of 2023) $ 175 $ 2 2024 300 4 2025 338 4 2026 365 4 2027 365 4 Thereafter 4,077 59 Total revenues to be recognized $ 5,620 $ 77 (1) Excludes intercompany transactions. Contract Liabilities from Revenues from Contracts with Customers Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2023 or 2022. As we discuss in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra Infrastructure drew against and fully exhausted SEFE’s letters of credit in April 2022 due to SEFE’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance. CONTRACT LIABILITIES (Dollars in millions) 2023 2022 Sempra: Contract liabilities at January 1 $ (252) $ (278) Revenue from performance obligations satisfied during reporting period 5 86 Payments received in advance (2) (105) Contract liabilities at June 30 (1) $ (249) $ (297) SDG&E: Contract liabilities at January 1 $ (79) $ (83) Revenue from performance obligations satisfied during reporting period 2 2 Contract liabilities at June 30 (2) $ (77) $ (81) (1) Balances at June 30, 2023 include $6 in Other Current Liabilities and $243 in Deferred Credits and Other. (2) Balances at June 30, 2023 include $4 in Other Current Liabilities and $73 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 Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) June 30, 2023 December 31, 2022 Sempra: Accounts receivable – trade, net (1) $ 1,828 $ 2,291 Accounts receivable – other, net 14 25 Due from unconsolidated affiliates – current (2) 7 9 Other long-term assets (3) 3 9 Total $ 1,852 $ 2,334 SDG&E: Accounts receivable – trade, net (1) $ 813 $ 799 Accounts receivable – other, net 10 12 Due from unconsolidated affiliates – current (2) 6 2 Other long-term assets (3) 2 6 Total $ 831 $ 819 SoCalGas: Accounts receivable – trade, net $ 856 $ 1,295 Accounts receivable – other, net 4 13 Other long-term assets (3) 1 3 Total $ 861 $ 1,311 (1) At June 30, 2023 and December 31, 2022, includes $123 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues. (2) Amount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists. (3) In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas enrolled residential and small business customers with past-due balances in long-term repayment plans.

REGULATORY MATTERS

REGULATORY MATTERS	6 Months Ended
REGULATORY MATTERS	Jun. 30, 2023
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report and provide updates to those discussions and information about new regulatory matters 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) June 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ 8 $ (110) Deferred income taxes recoverable in rates 429 296 Pension and PBOP plan obligations 3 11 Removal obligations (2,371) (2,248) Environmental costs 106 107 Sunrise Powerlink fire mitigation 121 123 Regulatory balancing accounts (1)(2) : Commodity – electric 181 220 Gas transportation 7 60 Safety and reliability 158 107 Public purpose programs (109) (69) Wildfire mitigation plan 519 375 Liability insurance premium 102 99 Other balancing accounts (342) (50) Other regulatory assets, net (2) 153 137 Total SDG&E (1,035) (942) SoCalGas: Deferred income taxes recoverable in rates 241 161 Pension and PBOP plan obligations (232) (170) Employee benefit costs 24 24 Removal obligations (591) (616) Environmental costs 37 38 Regulatory balancing accounts (1)(2) : Commodity – gas, including transportation (362) (257) Safety and reliability 644 575 Public purpose programs (152) (158) Liability insurance premium 22 23 Other balancing accounts 288 115 Other regulatory assets, net (2) 280 223 Total SoCalGas 199 (42) Sempra Infrastructure: Deferred income taxes recoverable in rates 78 78 Other regulatory assets 5 — Total Sempra Infrastructure 83 78 Total Sempra $ (753) $ (906) (1) At June 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $748 and $562, respectively, and for SoCalGas was $859 and $692, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. SEMPRA CALIFORNIA CPUC GRC The CPUC uses GRCs to set revenues 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 May 2022, SDG&E and SoCalGas filed their 2024 GRC applications requesting CPUC approval of test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. SDG&E and SoCalGas requested revenue requirements for 2024 of $3.0 billion and $4.4 billion, respectively. SDG&E and SoCalGas proposed post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. In October 2022, the CPUC issued a scoping ruling that set a schedule for the proceeding, including the expected issuance of a proposed decision in the second quarter of 2024. The CPUC has authorized SDG&E and SoCalGas to recognize the effects of the GRC final decision retroactive to January 1, 2024. SDG&E expects to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in the second half of 2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023. The results of the GRC may materially and adversely differ from what is contained in the GRC applications. CPUC Cost of Capital The CPUC approved the following cost of capital for SDG&E and SoCalGas that became effective on January 1, 2023 and will remain in effect through December 31, 2025, subject to the CCM. The CPUC will open a second phase of this cost of capital proceeding to evaluate the CCM. CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025 SDG&E SoCalGas Authorized weighting Return on Weighted return on rate base (1) Authorized weighting Return on Weighted 45.25 % 4.05 % 1.83 % Long-Term Debt 45.60 % 4.07 % 1.86 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 9.95 5.17 Common Equity 52.00 9.80 5.10 100.00 % 7.18 % 100.00 % 7.10 % (1) Total weighted return on rate base does not sum due to rounding differences. 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 currently effective TO5 settlement provides 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 until terminated by a notice provided at least six months before the end of the calendar year. Following such notice, SDG&E would file an updated rate request with an effective date of January 1 of the following year. We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that permanently ceased operations in June 2013, and in which SDG&E has a 20% ownership interest. We discuss SONGS further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. 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. SDG&E is responsible for approximately 20% of the total decommissioning cost. 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 Condensed 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 2022, the CPUC granted SDG&E authorization to access NDT funds of up to $81 million for forecasted 2023 costs. 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 Condensed Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 8. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated June 30, 2023 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 40 $ 1 $ (2) $ 39 Municipal bonds (2) 277 1 (12) 266 Other securities (3) 234 — (16) 218 Total debt securities 551 2 (30) 523 Equity securities 104 222 (4) 322 Short-term investments, primarily cash equivalents 24 — — 24 Receivables (payables), net (6) — — (6) Total $ 673 $ 224 $ (34) $ 863 December 31, 2022 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 40 $ 1 $ (1) $ 40 Municipal bonds 283 1 (14) 270 Other securities 248 — (21) 227 Total debt securities 571 2 (36) 537 Equity securities 111 194 (8) 297 Short-term investments, primarily cash equivalents 11 — — 11 Receivables (payables), net (4) — — (4) Total $ 689 $ 196 $ (44) $ 841 (1) Maturity dates are 2023-2053. (2) Maturity dates are 2023-2062. (3) Maturity dates are 2023-2072. 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) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Proceeds from sales $ 138 $ 155 $ 294 $ 397 Gross realized gains 6 3 8 14 Gross realized losses (3) (7) (6) (11) 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 Condensed 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 $523 million at June 30, 2023 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	6 Months Ended
INVESTMENTS IN UNCONSOLIDATED ENTITIES	Jun. 30, 2023
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 Condensed Consolidated Statements of Operations. See Note 11 for information on equity earnings and losses, both before and net of income tax, by segment. See Note 1 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 additional information concerning our equity method investments in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report. SEMPRA TEXAS UTILITIES Oncor Holdings We account for our 100% equity ownership interest in Oncor Holdings, which owns an 80.25% interest in Oncor, as an equity method investment. Due to the ring-fence measures, governance mechanisms and commitments in effect, we do not have the power to direct the significant activities of Oncor Holdings and Oncor. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information related to the restrictions on our ability to direct the significant activities of Oncor Holdings and Oncor. In the six months ended June 30, 2023 and 2022, Sempra contributed $178 million and $171 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $204 million and $170 million, respectively, to Sempra. We provide summarized income statement information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Operating revenues $ 1,343 $ 1,293 $ 2,635 $ 2,542 Operating expenses (976) (908) (2,000) (1,805) Income from operations 367 385 635 737 Interest expense (133) (108) (256) (216) Income tax expense (43) (52) (67) (94) Net income 197 226 296 417 Noncontrolling interest held by Texas Transmission Investment LLC (40) (46) (60) (84) Earnings attributable to Sempra (1) 157 180 236 333 (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. SEMPRA INFRASTRUCTURE Cameron LNG JV In the six months ended June 30, 2023 and 2022, Sempra Infrastructure contributed $6 million and $10 million, respectively, to Cameron LNG JV, and Cameron LNG JV distributed $198 million and $233 million, respectively, to Sempra Infrastructure. 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 $20 million at June 30, 2023, 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 SI Partners’ 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 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 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 recognizes 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 8). At June 30, 2023, the fair value of the Support Agreement was $23 million, of which $7 million is included in Other Current Assets and $16 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet. TAG In the six months ended June 30, 2023 and 2022, TAG distributed $36 million and $32 million, respectively, to Sempra Infrastructure.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	6 Months Ended
DEBT AND CREDIT FACILITIES	Jun. 30, 2023
Debt Disclosure [Abstract]
DEBT AND CREDIT FACILITIES	DEBT AND CREDIT FACILITIES The principal terms of our debt arrangements are described below and in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report. SHORT-TERM DEBT Committed Lines of Credit At June 30, 2023, Sempra had an aggregate capacity of $9.9 billion under eight primary committed lines of credit, which provide liquidity and support commercial paper programs. Because our commercial paper programs are supported by some of 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 in the following table. COMMITTED LINES OF CREDIT (Dollars in millions) June 30, 2023 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2027 $ 4,000 $ (813) $ — $ — $ 3,187 SDG&E October 2027 1,500 — — — 1,500 SoCalGas October 2027 1,200 (238) — — 962 SI Partners November 2024 1,000 — — — 1,000 IEnova and SI Partners September 2023 350 — (350) — — IEnova and SI Partners December 2023 150 — — — 150 IEnova and SI Partners February 2024 1,500 — (1,086) — 414 Port Arthur LNG March 2030 200 — — (15) 185 Total $ 9,900 $ (1,051) $ (1,436) $ (15) $ 7,398 Sempra, SDG&E and SoCalGas each 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 June 30, 2023, each entity was in compliance with this ratio under its respective credit facility. 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 facilities) of no more than 5.25 to 1.00 at the end of each quarter. At June 30, 2023, SI Partners was in compliance with this ratio. In March 2023, Port Arthur LNG entered into a seven-year initial working capital facility agreement with a syndicate of lenders expiring in March 2030. The credit facility permits borrowings of up to $200 million, which bear interest by reference to Term SOFR, plus the applicable margin and a credit adjustment spread. The credit facility also provides for the issuance of up to $200 million of letters of credit. Uncommitted Line of Credit ECA LNG Phase 1 has an uncommitted line of credit, which is generally used for working capital requirements, with an aggregate capacity of $200 million of which $32 million was outstanding at June 30, 2023. The amounts outstanding are before reductions of any unamortized discounts. Borrowings can be in U.S. dollars or Mexican pesos. At June 30, 2023, 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. In June 2023, the facility was amended to extend the expiration date to August 2024 and replace the LIBOR reference rate plus 105 bps with the SOFR reference rate plus 115 bps. As such, borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month SOFR plus 115 bps. 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 June 30, 2023, we had $514 million in standby letters of credit outstanding under these agreements. UNCOMMITTED LETTERS OF CREDIT (Dollars in millions) June 30, 2023 Expiration date range Uncommitted letters of credit outstanding SDG&E January 2024 - May 2024 $ 15 SoCalGas November 2023 - October 2024 20 Sempra Infrastructure July 2023 - October 2043 311 Parent and other September 2023 - June 2024 168 Total $ 514 Term Loan In July 2022, SoCalGas entered into an $800 million, 364-day term loan agreement with a maturity date of July 6, 2023. In August 2022, SoCalGas borrowed $800 million, net of negligible debt issuance costs, under the term loan agreement. The borrowing bore interest at benchmark rates plus 70 bps and was due in full upon maturity. SoCalGas used the proceeds for payment of a portion of the costs relating to litigation pertaining to the Leak. In the second quarter of 2023, SoCalGas repaid the term loan in full. Weighted-Average Interest Rates The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES June 30, 2023 December 31, 2022 Sempra 5.92 % 5.57 % SDG&E — 4.76 SoCalGas 5.14 4.71 LONG-TERM DEBT SDG&E In March 2023, SDG&E issued $800 million aggregate principal amount of 5.35% first mortgage bonds due in full upon maturity on April 1, 2053 and received proceeds of $783 million (net of debt discount, underwriting discounts and debt issuance costs of $17 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SDG&E used the net proceeds for general corporate purposes, including repayment of commercial paper and other indebtedness. SoCalGas In May 2023, SoCalGas issued $500 million aggregate principal amount of 5.20% first mortgage bonds due in full upon maturity on June 1, 2033 and received proceeds of $495 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $500 million aggregate principal amount of 5.75% first mortgage bonds due in full upon maturity on June 1, 2053 and received proceeds of $493 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). Each series of first mortgage bonds is redeemable prior to maturity, subject to its terms, and in certain circumstances subject to make-whole provisions. SoCalGas used the net proceeds to repay its $300 million senior unsecured floating rate notes prior to their September 2023 scheduled maturity, a portion of its $800 million term loan and other general corporate purposes. Sempra In June 2023, Sempra issued $550 million aggregate principal amount of 5.40% senior unsecured notes due in full upon maturity on August 1, 2026 and received proceeds of $545 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $700 million aggregate principal amount of 5.50% senior unsecured notes due in full upon maturity on August 1, 2033 and received proceeds of $692 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). Each series of notes is redeemable prior to maturity, subject to its terms, and in certain circumstances subject to make-whole provisions. We intend to use the net proceeds for general corporate purposes, including repayment of commercial paper and potentially other indebtedness. Sempra Infrastructure ECA LNG Phase 1 ECA LNG Phase 1 has a five-year loan agreement with a syndicate of seven external lenders that matures in December 2025 for an aggregate principal amount of up to $1.3 billion. IEnova and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest of 83.4% and 16.6%, respectively. At June 30, 2023 and December 31, 2022, $708 million and $575 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 8.20% and 7.54%, respectively. Port Arthur LNG In March 2023, Port Arthur LNG entered into a term loan facility agreement with a syndicate of lenders for an aggregate principal amount of approximately $6.8 billion. Proceeds from the loans will be used to finance the cost of construction of the PA LNG Phase 1 project. The loans mature on March 20, 2030 and bear interest by reference to Term SOFR, plus the applicable margin and a credit adjustment spread. The applicable margin prior to completion of the PA LNG Phase 1 project (which occurs upon the satisfaction or waiver of a series of customary operational, technical, environmental and social and other tests and conditions that generally would not be fully met until after the commercial operations date) is 2.00% and on completion and thereafter is 2.25%. The principal amounts outstanding on the loans must be repaid in quarterly installments, commencing on the earlier of (i) the first quarterly payment date occurring more than three calendar months following completion of the PA LNG Phase 1 project and (ii) April 20, 2029. Under the terms of the loan agreement, at least 60% of the projected outstanding balance is required to be hedged during construction and over the underlying 20-year notional amortization period. As we discuss in Note 7, Port Arthur LNG entered into hedging instruments in satisfaction of this requirement in March 2023. An upfront equity funding amount of $4.7 billion is required to have been contributed to Port Arthur LNG for construction costs as a condition to the initial advance of term loans under the agreement (other than advances for fees, interest, expenses and certain other specified costs). Port Arthur LNG paid $200 million in debt issuance costs at closing. Additionally, the loan agreement and the related working capital facility agreement that we discuss above require payment of commitment fees calculated at a rate per annum equal to 30% of the applicable margin for Term SOFR loans multiplied by the outstanding debt commitments, and additional administrative fees. At June 30, 2023, $228 million of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.58%. In connection with this loan agreement, SI Partners and ConocoPhillips have collectively provided commitments for approximately $2.8 billion in equity funding for the benefit of Port Arthur LNG for their respective affiliate’s share of the equity funding of anticipated construction costs of the PA LNG Phase 1 project in excess of the upfront equity funding amount of $4.7 billion. The amount of each commitment is based on each of SI Partners’ and ConocoPhillips’ proportionate indirect ownership interest in Port Arthur LNG of 70% and 30%, respectively. The obligation under these guarantees will be reduced as their respective affiliates fund their direct proportionate interest of capital calls. Such equity funding can be called upon by Port Arthur LNG to fund project costs or, upon the taking of an enforcement action under the terms of Port Arthur LNG’s finance documents, to pay its senior debt obligations. The pari passu secured obligations under the related finance documents are secured by a first priority lien (subject to customary permitted encumbrances) in substantially all of the assets of Port Arthur LNG, including the equity interests in, and real property

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	6 Months Ended
DERIVATIVE FINANCIAL INSTRUMENTS	Jun. 30, 2023
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 Condensed 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 amounts related to terminations or early settlements of interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Condensed 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 of variability of future cash flows of a given revenue or expense item, 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 derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, 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 limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. 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 Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power. ▪ 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 Condensed Consolidated Statements of Operations. ▪ Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations. ▪ From time to time, our various businesses, including SDG&E and SoCalGas, may use other derivatives to hedge exposures such as GHG allowances. The following table summarizes net energy derivative volumes. NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) Commodity Unit of measure June 30, 2023 December 31, 2022 Sempra: Natural gas MMBtu 380 254 Electricity MWh — 1 Congestion revenue rights MWh 35 42 SDG&E: Natural gas MMBtu 20 15 Congestion revenue rights MWh 35 42 SoCalGas: Natural gas MMBtu 271 224 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. In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap. As we discuss in Note 6, a minimum of 60% of the projected amount of term loans outstanding is required to be hedged under the Port Arthur LNG term loan facility agreement. In March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps with 17 counterparties to hedge the variability in cash flows related to the SOFR-based component of interest payments on forecasted loans outstanding under the agreement. The notional amounts of the interest rate swaps generally increase in proportion to the forecasted borrowings up to a maximum amount of $4.2 billion prior to the maturity of the term loans on March 20, 2030. Under the interest rate swaps, which are designated as cash flow hedges, Port Arthur LNG receives interest at Term SOFR and pays interest at a fixed rate of 3.23% based on amortizing notional amounts maturing in 2048. The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments and the contingent interest rate swap. INTEREST RATE DERIVATIVES (Dollars in millions) June 30, 2023 December 31, 2022 Notional debt Maturities Notional debt Maturities Sempra: Cash flow hedges (1) $ 4,454 2023-2048 $ 294 2023-2034 (1) At June 30, 2023 and December 31, 2022, cash flow hedges accrued interest based on a notional of $491 and $294, respectively. FOREIGN CURRENCY DERIVATIVES We may 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 fixed 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. The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) June 30, 2023 December 31, 2022 Notional amount Maturities Notional amount Maturities Sempra: Cross-currency swaps $ — — $ 306 2023 Other foreign currency derivatives 65 2023-2024 111 2023-2024 FINANCIAL STATEMENT PRESENTATION The Condensed 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 Condensed 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 CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) June 30, 2023 Current assets: Fixed-price contracts and other derivatives (1) Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ 16 $ 46 $ — $ (2) Foreign exchange instruments — — (15) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 251 35 (236) (42) Associated offsetting commodity contracts (232) (35) 232 35 Commodity contracts subject to rate recovery 20 17 (64) (17) Associated offsetting commodity contracts (12) (4) 12 4 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 43 59 (61) (18) Additional cash collateral for commodity contracts not subject to rate recovery 143 — — — Additional cash collateral for commodity contracts subject to rate recovery 70 — — — Total (2) $ 256 $ 59 $ (61) $ (18) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 18 $ 17 $ (26) $ (8) Associated offsetting commodity contracts (11) (4) 11 4 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 7 13 (5) — Additional cash collateral for commodity contracts subject to rate recovery 69 — — — Total (2) $ 76 $ 13 $ (5) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 2 $ — $ (38) $ (9) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 1 — (37) (9) Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 2 $ — $ (37) $ (9) (1) Included in Other Current Assets for SoCalGas. (2) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED) (Dollars in millions) December 31, 2022 Current assets: Fixed-price contracts and other derivatives (1) Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ 10 $ 33 $ — $ — Foreign exchange instruments — — (7) (1) Interest rate and foreign exchange instruments — — (105) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 480 133 (399) (132) Associated offsetting commodity contracts (301) (39) 301 39 Commodity contracts subject to rate recovery 138 27 (97) (2) Associated offsetting commodity contracts (27) (2) 27 2 Interest rate instrument 33 — — — Net amounts presented on the balance sheet 333 152 (280) (94) Additional cash collateral for commodity contracts not subject to rate recovery 451 — — — Additional cash collateral for commodity contracts subject to rate recovery 18 — — — Total (2) $ 802 $ 152 $ (280) $ (94) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 107 $ 27 $ (13) $ (2) Associated offsetting commodity contracts (12) (2) 12 2 Net amounts presented on the balance sheet 95 25 (1) — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total (2) $ 112 $ 25 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 31 $ — $ (84) $ — Associated offsetting commodity contracts (15) — 15 — Net amounts presented on the balance sheet 16 — (69) — Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 17 $ — $ (69) $ — (1) Included in Other Current Assets for SoCalGas. (2) 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 Condensed Consolidated Statements of Operations and in OCI and AOCI. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax gain (loss) reclassified Three months ended June 30, Three months ended June 30, 2023 2022 Location 2023 2022 Sempra: Interest rate instruments $ 94 $ 13 Interest Expense $ — $ — Interest rate instruments 41 50 Equity Earnings (1) 14 (13) Foreign exchange instruments (2) — Revenues: Energy- Related Businesses — 1 Other Income (Expense), Net (1) (1) Foreign exchange instruments (1) — Equity Earnings (1) (1) — Interest rate and foreign exchange instruments — 4 Interest Expense 1 1 Total $ 132 $ 67 $ 13 $ (12) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1) $ (1) Six months ended June 30, Six months ended June 30, 2023 2022 Location 2023 2022 Sempra: Interest rate instruments $ 17 $ 35 Interest Expense $ — $ 1 Interest rate instruments 24 144 Equity Earnings (1) 21 (27) Foreign exchange instruments (8) (3) Revenues: Energy- Related Businesses — 2 Other Income (Expense), Net (2) (1) Foreign exchange instruments (6) (2) Equity Earnings (1) (2) 1 Interest rate and foreign exchange instruments 7 13 Interest Expense 1 1 Other Income (Expense), Net 6 6 Total $ 34 $ 187 $ 24 $ (17) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1) $ (1) (1) Equity earnings at our foreign equity method investees are recognized after tax. For Sempra, we expect that net gains before NCI of $23 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $14 million attributable to 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 June 30, 2023 is approximately 25 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 16 years. The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended June 30, Six months ended June 30, Location 2023 2022 2023 2022 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ 253 $ (151) $ 702 $ (228) Commodity contracts subject to rate recovery Cost of Natural Gas (20) (4) (47) (4) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (27) (24) (18) (6) Interest rate instrument Interest Expense — — (47) — Total $ 206 $ (179) $ 590 $ (238) SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ (27) $ (24) $ (18) $ (6) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (20) $ (4) $ (47) $ (4) CREDIT RISK RELATED 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 June 30, 2023 and December 31, 2022 was $50 million and $106 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at June 30, 2023 and December 31, 2022 was $46 million and $69 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at June 30, 2023 or December 31, 2022. At June 30, 2023, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $50 million and $46 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
FAIR VALUE MEASUREMENTS	Jun. 30, 2023
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. 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 June 30, 2023 and December 31, 2022. 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. We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2022. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 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: ▪ 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 instruments 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 5, 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) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 22 $ 2 $ — $ 24 Equity securities 318 4 — 322 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 25 14 — 39 Municipal bonds — 266 — 266 Other securities — 218 — 218 Total debt securities 25 498 — 523 Total nuclear decommissioning trusts (1) 365 504 — 869 Short-term investments held in Rabbi Trust 51 — — 51 Interest rate instruments — 62 — 62 Commodity contracts not subject to rate recovery — 19 — 19 Effect of netting and allocation of collateral (2) 143 — — 143 Commodity contracts subject to rate recovery — 1 20 21 Effect of netting and allocation of collateral (2) 65 — 5 70 Support Agreement, net of related guarantee fees — — 23 23 Total $ 624 $ 586 $ 48 $ 1,258 Liabilities: Interest rate instruments $ — $ 2 $ — $ 2 Foreign exchange instruments — 15 — 15 Commodity contracts not subject to rate recovery — 11 — 11 Commodity contracts subject to rate recovery 14 51 — 65 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 79 $ — $ 79 (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 (CONTINUED) (Dollars in millions) Level 1 Level 2 Level 3 Total Fair value at December 31, 2022 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 10 $ 1 $ — $ 11 Equity securities 293 4 — 297 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 27 13 — 40 Municipal bonds — 270 — 270 Other securities — 227 — 227 Total debt securities 27 510 — 537 Total nuclear decommissioning trusts (1) 330 515 — 845 Short-term investments held in Rabbi Trust 55 — — 55 Interest rate instruments — 76 — 76 Commodity contracts not subject to rate recovery — 273 — 273 Effect of netting and allocation of collateral (2) 451 — — 451 Commodity contracts subject to rate recovery 82 19 35 136 Effect of netting and allocation of collateral (2) 12 — 6 18 Support Agreement, net of related guarantee fees — — 17 17 Total $ 930 $ 883 $ 58 $ 1,871 Liabilities: Foreign exchange instruments $ — $ 8 $ — $ 8 Interest rate and foreign exchange instruments — 105 — 105 Commodity contracts not subject to rate recovery — 191 — 191 Commodity contracts subject to rate recovery — 70 — 70 Total $ — $ 374 $ — $ 374 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) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 22 $ 2 $ — $ 24 Equity securities 318 4 — 322 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 25 14 — 39 Municipal bonds — 266 — 266 Other securities — 218 — 218 Total debt securities 25 498 — 523 Total nuclear decommissioning trusts (1) 365 504 — 869 Commodity contracts subject to rate recovery — — 20 20 Effect of netting and allocation of collateral (2) 64 — 5 69 Total $ 429 $ 504 $ 25 $ 958 Liabilities: Commodity contracts subject to rate recovery $ 14 $ 5 $ — $ 19 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 5 $ — $ 5 Fair value at December 31, 2022 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 10 $ 1 $ — $ 11 Equity securities 293 4 — 297 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 27 13 — 40 Municipal bonds — 270 — 270 Other securities — 227 — 227 Total debt securities 27 510 — 537 Total nuclear decommissioning trusts (1) 330 515 — 845 Commodity contracts subject to rate recovery 82 3 35 120 Effect of netting and allocation of collateral (2) 11 — 6 17 Total $ 423 $ 518 $ 41 $ 982 Liabilities: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Total $ — $ 1 $ — $ 1 (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) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Effect of netting and allocation of collateral (1) 1 — — 1 Total $ 1 $ 1 $ — $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 46 $ — $ 46 Total $ — $ 46 $ — $ 46 Fair value at December 31, 2022 Assets: Commodity contracts subject to rate recovery $ — $ 16 $ — $ 16 Effect of netting and allocation of collateral (1) 1 — — 1 Total $ 1 $ 16 $ — $ 17 Liabilities: Commodity contracts subject to rate recovery $ — $ 69 $ — $ 69 Total $ — $ 69 $ — $ 69 (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) Three months ended June 30, 2023 2022 Balance at April 1 $ 30 $ 58 Realized and unrealized losses (4) (30) Allocated transmission instruments (2) (6) Settlements (4) 11 Balance at June 30 $ 20 $ 33 Change in unrealized losses relating to instruments still held at June 30 $ (7) $ (23) Six months ended June 30, 2023 2022 Balance at January 1 $ 35 $ 54 Realized and unrealized losses (8) (23) Allocated transmission instruments (2) (6) Settlements (5) 8 Balance at June 30 $ 20 $ 33 Change in unrealized losses relating to instruments still held at June 30 $ (9) $ (18) (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. 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 2023 $ (3.09) to $ 10.71 $ (0.56) 2022 (3.67) to 6.96 (0.70) The impact associated with discounting is not significant. 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 significantly higher (lower) fair value measurement. We summarize CRR volumes in Note 7. 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 June 30 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Weighted-average 2023 $ 22.75 to $ 117.50 $ 74.02 2022 25.25 to 125.00 66.36 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 7. 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 Condensed 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) Three months ended June 30, 2023 2022 Balance at April 1 $ 24 $ 12 Realized and unrealized gains (1) 1 6 Settlements (2) (2) Balance at June 30 (2) $ 23 $ 16 Change in unrealized gains relating to instruments still held at June 30 $ 1 $ 5 Six months ended June 30, 2023 2022 Balance at January 1 $ 17 $ 7 Realized and unrealized gains (1) 10 14 Settlements (4) (5) Balance at June 30 (2) $ 23 $ 16 Change in unrealized gains relating to instruments still held at June 30 $ 9 $ 13 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Condensed Consolidated Statements of Operations. (2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet. The fair value of the Support Agreement, net of related guarantee fees, is based on a discounted cash flow model using a probability of default and survival methodology. Our estimate of fair value considers inputs such as third-party default rates, credit ratings, recovery rates, and risk-adjusted discount rates, which may be readily observable, market corroborated or generally unobservable inputs. Because CFIN’s credit rating and related default and survival rates are unobservable inputs that are significant to the valuation, the Support Agreement, net of related guarantee fees, is classified as Level 3. We assigned CFIN an internally developed credit rating of A3 and relied on default rate data published by Moody’s to assign a probability of default. A hypothetical change in the credit rating up or down one notch could result in a significant change in the fair value of the Support Agreement. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, 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 Condensed Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value Level 1 Level 2 Level 3 Total June 30, 2023 Sempra: Long-term note receivable (1) $ 326 $ — $ — $ 296 $ 296 Long-term amounts due to unconsolidated affiliates 287 — 251 — 251 Total long-term debt (2) 27,419 — 24,630 — 24,630 SDG&E: Total long-term debt (3) $ 8,600 $ — $ 7,535 $ — $ 7,535 SoCalGas: Total long-term debt (4) $ 6,759 $ — $ 6,270 $ — $ 6,270 December 31, 2022 Sempra: Long-term note receivable (1) $ 318 $ — $ — $ 286 $ 286 Long-term amounts due to unconsolidated affiliates 301 — 263 — 263 Total long-term debt (2) 24,513 — 21,549 — 21,549 SDG&E: Total long-term debt (3) $ 7,800 $ — $ 6,726 $ — $ 6,726 SoCalGas: Total long-term debt (4) $ 6,059 $ — $ 5,538 $ — $ 5,538 (1) Before allowances for credit losses of $6 and $7 at June 30, 2023 and December 31, 2022, respectively. Excludes unamortized transaction costs of $4 and $5 at June 30, 2023 and December 31, 2022, respectively. (2) Before reductions of unamortized discount and debt issuance costs of $325 and $289 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,351 and $1,343 at June 30, 2023 and December 31, 2022, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $85 and $70 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,241 and $1,256 at June 30, 2023 and December 31, 2022, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $57 and $48 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $110 and $87 at June 30, 2023 and December 31, 2022, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 9.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	6 Months Ended
SAN ONOFRE NUCLEAR GENERATING STATION	Jun. 30, 2023
Regulated Operations [Abstract]
SAN ONOFRE NUCLEAR GENERATING STATION	REGULATORY MATTERS We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report and provide updates to those discussions and information about new regulatory matters 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) June 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ 8 $ (110) Deferred income taxes recoverable in rates 429 296 Pension and PBOP plan obligations 3 11 Removal obligations (2,371) (2,248) Environmental costs 106 107 Sunrise Powerlink fire mitigation 121 123 Regulatory balancing accounts (1)(2) : Commodity – electric 181 220 Gas transportation 7 60 Safety and reliability 158 107 Public purpose programs (109) (69) Wildfire mitigation plan 519 375 Liability insurance premium 102 99 Other balancing accounts (342) (50) Other regulatory assets, net (2) 153 137 Total SDG&E (1,035) (942) SoCalGas: Deferred income taxes recoverable in rates 241 161 Pension and PBOP plan obligations (232) (170) Employee benefit costs 24 24 Removal obligations (591) (616) Environmental costs 37 38 Regulatory balancing accounts (1)(2) : Commodity – gas, including transportation (362) (257) Safety and reliability 644 575 Public purpose programs (152) (158) Liability insurance premium 22 23 Other balancing accounts 288 115 Other regulatory assets, net (2) 280 223 Total SoCalGas 199 (42) Sempra Infrastructure: Deferred income taxes recoverable in rates 78 78 Other regulatory assets 5 — Total Sempra Infrastructure 83 78 Total Sempra $ (753) $ (906) (1) At June 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $748 and $562, respectively, and for SoCalGas was $859 and $692, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. SEMPRA CALIFORNIA CPUC GRC The CPUC uses GRCs to set revenues 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 May 2022, SDG&E and SoCalGas filed their 2024 GRC applications requesting CPUC approval of test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. SDG&E and SoCalGas requested revenue requirements for 2024 of $3.0 billion and $4.4 billion, respectively. SDG&E and SoCalGas proposed post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. In October 2022, the CPUC issued a scoping ruling that set a schedule for the proceeding, including the expected issuance of a proposed decision in the second quarter of 2024. The CPUC has authorized SDG&E and SoCalGas to recognize the effects of the GRC final decision retroactive to January 1, 2024. SDG&E expects to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in the second half of 2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023. The results of the GRC may materially and adversely differ from what is contained in the GRC applications. CPUC Cost of Capital The CPUC approved the following cost of capital for SDG&E and SoCalGas that became effective on January 1, 2023 and will remain in effect through December 31, 2025, subject to the CCM. The CPUC will open a second phase of this cost of capital proceeding to evaluate the CCM. CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025 SDG&E SoCalGas Authorized weighting Return on Weighted return on rate base (1) Authorized weighting Return on Weighted 45.25 % 4.05 % 1.83 % Long-Term Debt 45.60 % 4.07 % 1.86 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 9.95 5.17 Common Equity 52.00 9.80 5.10 100.00 % 7.18 % 100.00 % 7.10 % (1) Total weighted return on rate base does not sum due to rounding differences. 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 currently effective TO5 settlement provides 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 until terminated by a notice provided at least six months before the end of the calendar year. Following such notice, SDG&E would file an updated rate request with an effective date of January 1 of the following year. We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that permanently ceased operations in June 2013, and in which SDG&E has a 20% ownership interest. We discuss SONGS further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. 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. SDG&E is responsible for approximately 20% of the total decommissioning cost. 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 Condensed 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 2022, the CPUC granted SDG&E authorization to access NDT funds of up to $81 million for forecasted 2023 costs. 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 Condensed Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 8. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated June 30, 2023 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 40 $ 1 $ (2) $ 39 Municipal bonds (2) 277 1 (12) 266 Other securities (3) 234 — (16) 218 Total debt securities 551 2 (30) 523 Equity securities 104 222 (4) 322 Short-term investments, primarily cash equivalents 24 — — 24 Receivables (payables), net (6) — — (6) Total $ 673 $ 224 $ (34) $ 863 December 31, 2022 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 40 $ 1 $ (1) $ 40 Municipal bonds 283 1 (14) 270 Other securities 248 — (21) 227 Total debt securities 571 2 (36) 537 Equity securities 111 194 (8) 297 Short-term investments, primarily cash equivalents 11 — — 11 Receivables (payables), net (4) — — (4) Total $ 689 $ 196 $ (44) $ 841 (1) Maturity dates are 2023-2053. (2) Maturity dates are 2023-2062. (3) Maturity dates are 2023-2072. 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) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Proceeds from sales $ 138 $ 155 $ 294 $ 397 Gross realized gains 6 3 8 14 Gross realized losses (3) (7) (6) (11) 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 Condensed 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 $523 million at June 30, 2023 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
COMMITMENTS AND CONTINGENCIES	Jun. 30, 2023
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 June 30, 2023, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $222 million for Sempra, including $6 million for SDG&E and $142 million for SoCalGas. Amounts for Sempra and SoCalGas include $126 million for matters related to the Leak, which we discuss below. 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. Litigation. In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) pending against SoCalGas and Sempra related to the Leak for a payment of up to $1.8 billion. Over 99% of the Individual Plaintiffs participated and submitted valid releases, and SoCalGas paid $1.79 billion in 2022 under the agreement. The Individual Plaintiffs who have not participated in the settlement (the Remaining Individual Plaintiffs) are able to continue to pursue their claims. The Individual Plaintiffs’ cases were coordinated before a single court in the LA Superior Court for pretrial management under a consolidated master complaint filed in November 2017. The consolidated master 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 and wrongful death against SoCalGas and Sempra. The consolidated master 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 July 2023, the LA Superior Court issued an order to 243 Remaining Individual Plaintiffs who did not respond to discovery requests to show why their cases should not be dismissed. In addition, as of July 31, 2023, new lawsuits on behalf of approximately 388 new plaintiffs have been filed against SoCalGas and Sempra since the September 2021 settlement. These cases are being joined in the same coordinated proceeding in the LA Superior Court under the consolidated master complaint. 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 four shareholder derivative actions that were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra and/or SoCalGas were joined in an Amended Consolidated Shareholder Derivative Complaint filed in the same coordinated proceeding in the LA Superior Court, which was dismissed with prejudice in January 2021, and in June 2023, the Court of Appeal affirmed the dismissal. Plaintiffs have sought review in the California Supreme Court. The LA Superior Court dismissed the remaining fourth action with prejudice in November 2022. The plaintiffs have appealed this dismissal. Regulatory Proceedings. 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, as well as evaluating the impacts of reducing or eliminating the Aliso Canyon natural gas storage facility using the established framework and models. The next phase of the proceeding included engaging a consultant to analyze alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2035 timeframe, and to 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 2021, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting an 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 June 30, 2023, the Aliso Canyon natural gas storage facility had a net book value of $976 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, which could be material, or we could incur materially higher than expected operating costs and/or be required to make material additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Regulatory Proceeding – Subject to an Agreement to Resolve. In June 2019, the CPUC opened an OII (the Leak OII) to investigate and consider, among other things, 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 SED, as well as to determine the amount 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. In October 2022, SoCalGas executed a settlement agreement with SED and the Public Advocates Office at the CPUC to resolve all aspects of the Leak OII. The settlement agreement provides for financial penalties, certain costs that SoCalGas will reimburse, a violation of California Public Utilities Code section 451, and costs previously incurred by SoCalGas for which it will not seek recovery from ratepayers, among other provisions. The settlement agreement was filed with and is subject to approval by the CPUC. Insurance and Accounting and Other Impacts. Since 2015, SoCalGas has incurred significant costs related to the Leak, including costs to defend against and settle civil litigation arising from the Leak. Other than insurance for directors’ and officers’ liability, we have exhausted all of our insurance for 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. In the three months and six months ended June 30, 2022, SoCalGas recorded total charges of $45 million ($32 million after tax) and $137 million ($98 million after tax), respectively, in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations related to the litigation and regulatory proceedings associated with the Leak. At June 30, 2023, $126 million is accrued in Reserve for Aliso Canyon Costs and $2 million is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. These accruals do not include any amounts beyond what has been estimated to resolve the matters that we describe above in “Litigation” and “Regulatory Proceedings,” nor any amounts that may be necessary to resolve threatened litigation, other potential litigation or other costs, in each case 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. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued, which could be significant. Sempra Infrastructure Energía Costa Azul We describe below certain land disputes and permit challenges affecting our ECA Regas Facility. Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities under construction and in development are expected to be situated or on which portions of the ECA Regas Facility that would be necessary for the operation of such ECA LNG liquefaction facilities are situated. 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 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. The proceeding in the Agrarian Court has concluded; however, the administrative procedure at SEDATU may continue if SEDATU decides to reopen the matter. In addition, an area of real property on which part of the ECA Regas Facility is situated is subject to a claim in the federal Agrarian Court, 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 of the ECA Regas Facility and dismissed the appeal. The plaintiff filed a federal appeal against the appellate court ruling. A ruling from the Federal Collegiate Circuit Court is pending. 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, holding that the natural gas liquefaction activities did not violate the injunction. The claimants appealed this ruling but were not successful. The claimant’s underlying challenge to the permits remains pending. Litigation Related to Regulatory and Other Actions by the Mexican Government Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective on March 10, 2021, and SENER, the CRE and Centro Nacional de Control de Energía (Mexico’s National Center for Energy Control) were to have 180 calendar days to modify, as necessary, all resolutions, policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. However, a Mexican court issued a suspension of the amendments on March 19, 2021. In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law, but the qualified majority of eight votes out of 11 as is required in matters Sonora Pipeline – Resolved 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, resulting in a suspension order in 2016 that prohibited construction through the Bácum community territory. Because Sempra Infrastructure did not believe the 2016 suspension order prohibited construction in the remainder of the Yaqui territory, construction was completed, and commercial operations began in May 2017. Following the start of commercial operations, Sempra Infrastructure reported damage to the Guaymas-El Oro segment 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 to remain in place until the appeals process was exhausted. Following a request by the CFE to dismiss the appeal based on the plan to re-route the portion of the pipeline that is in the Yaqui territory, in December 2022, the court of appeals reversed the federal district court’s ruling and ordered the district court to issue a new ruling that takes into account the planned re-routing of the pipeline. In February 2023, the district court issued a new ruling and resolved to dismiss the case, which was not appealed and, in March 2023, the district court declared that the case was definitively concluded. Other Litigation RBS Sempra Commodities Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against RBS (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE, a subsidiary of RBS Sempra Commodities. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million (approximately $57 million in U.S. dollars at June 30, 2023), plus costs and interest. In October 2020, the High Court of Justice assessed costs and interest to be approximately £21 million (approximately $27 million in U.S. dollars at June 30, 2023) as of that date, with interest continuing to accrue. The Defendants appealed and, in May 2021, the Court of Appeal set aside the High Court of Justice’s decision and ordered a retrial. In July 2022, the Supreme Court of the U.K. denied the Liquidating Companies application for permission to appeal the Court of Appeal’s decision. No date has been scheduled for the retrial. J.P. Morgan Chase & Co., which acquired RBS SEE and later sold it to Mercuria Energy Group, Ltd., previously notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and J.P. Morgan Chase & Co. has in turn sought indemnity from Sempra and RBS. Asbestos Claims Against EFH Subsidiaries Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of July 31, 2023, two lawsuits are pending. Additionally, approximately 28,000 proofs of claim were filed, but not discharged, in advance of a December 2015 deadline to file a proof of claim in the EFH bankruptcy proceeding on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. The costs to defend or resolve such claims and the amount of damages that may be incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects. Ordinary Course Litigation We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases. LEASES We discuss leases further in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. Lessee Accounting We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities. SDG&E entered into an energy storage agreement that commenced in the second quarter of 2023 and expires in 2033. SDG&E recorded an operating lease right-of-use asset and operating lease liability of $101 million. Undiscounted lease payments are $9 million in 2023, $13 million in each of 2024 through 2027 and $66 million thereafter. Leases That Have Not Yet Commenced SDG&E has entered into four energy storage agreements, of which SDG&E expects one will commence in the second half of 2023, two will commence in 2024 and one will commence in 2025. SDG&E expects the future minimum lease payments to be $1 million in 2023, $32 million in 2024, $41 million in each of 2025 and 2026, $40 million in 2027 and $377 million thereafter until expiration in 2039. SoCalGas has entered into a fleet vehicle agreement, under which SoCalGas expects leases will commence throughout the second half of 2023 and first quarter of 2024. SoCalGas expects the future minimum lease payments to be $1 million in each of 2024 through 2027 and $6 million thereafter until expiration in 2032. Lessor Accounting Sempra Infrastructure is a lessor for certain of its natural gas and ethane pipelines, compressor stations, liquid petroleum gas storage facilities, a rail facility and refined products terminals, which we account for as operating or sales-type leases. We provide information below for leases for which we are the lessor. LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sales-type leases: Interest income $ 1 $ 2 $ 3 $ 4 Total revenues from sales-type leases (1) $ 1 $ 2 $ 3 $ 4 Operating leases: Fixed lease payments $ 76 $ 70 $ 156 $ 140 Variable lease payments 14 3 16 4 Total revenues from operating leases (1) $ 90 $ 73 $ 172 $ 144 Depreciation expense $ 15 $ 14 $ 30 $ 27 (1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations. CONTRACTUAL COMMITMENTS We discuss below significant changes in the first six months of 2023 to contractual commitments discussed in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. Natural Gas Contracts Sempra Infrastructure’s natural gas contracts and natural gas storage and transportation commitments have increased by approximately $863 million since December 31, 2022, primarily from entering into new storage and transportation contracts in the first six months of 2023. We expect future payments to decrease by $27 million in 2023, and increase by $23 million in 2024, $33 million in each of 2025 and 2026, $30 million in 2027 and $771 million thereafter through expiration in 2059 compared to December 31, 2022. LNG Purchase Agreement Sempra Infrastructure has an SPA for the supply of LNG to the ECA Regas Facility. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2023 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At June 30, 2023, we expect the commitment amount to decrease by $841 million in 2023, $87 million in 2024, $65 million in 2025, $87 million in 2026, $98 million in 2027 and $208 million thereafter (through contract termination in 2029) compared to December 31, 2022, reflecting changes in estimated forward prices since December 31, 2022 and actual transactions for the first six months of 2023. These LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted as of June 30, 2023, under the agreement are delivered. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amount provided under the agreement due to the supplier electing to divert cargoes as allowed by the agreement. ENVIRONMENTAL ISSUES We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $48 million for Sempra, $17 million for SDG&E and $13 million for SoCalGas at June 30, 2023.

SEGMENT INFORMATION

SEGMENT INFORMATION	6 Months Ended
SEGMENT INFORMATION	Jun. 30, 2023
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 Utilitie s holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electricity 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 L.P., which owns Sharyland Utilities, L.L.C., 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. 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. 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 Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations. SEGMENT INFORMATION (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 REVENUES SDG&E $ 1,262 $ 1,399 $ 2,915 $ 2,844 SoCalGas 1,467 1,501 5,261 3,494 Sempra Infrastructure 660 689 1,856 1,113 Adjustments and eliminations (2) (2) (1) — Intersegment revenues (1) (52) (40) (136) (84) Total $ 3,335 $ 3,547 $ 9,895 $ 7,367 DEPRECIATION AND AMORTIZATION SDG&E $ 268 $ 244 $ 530 $ 483 SoCalGas 208 188 414 375 Sempra Infrastructure 70 67 139 132 All other 3 2 5 4 Total $ 549 $ 501 $ 1,088 $ 994 INTEREST INCOME SDG&E $ 4 $ 1 $ 5 $ 1 SoCalGas 1 1 5 1 Sempra Infrastructure 6 9 21 30 All other 6 4 10 8 Total $ 17 $ 15 $ 41 $ 40 INTEREST EXPENSE SDG&E $ 123 $ 114 $ 241 $ 220 SoCalGas 71 45 140 85 Sempra Infrastructure 25 32 120 59 All other 99 81 183 151 Intercompany eliminations (1) (1) (1) (1) Total $ 317 $ 271 $ 683 $ 514 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 4 $ 42 $ 11 $ 106 SoCalGas (21) 19 73 103 Sempra Infrastructure 201 70 531 161 All other (9) (51) (64) 44 Total $ 175 $ 80 $ 551 $ 414 EQUITY EARNINGS Equity earnings, before income tax: Sempra Texas Utilities $ 2 $ 3 $ 3 $ 5 Sempra Infrastructure 151 156 282 297 153 159 285 302 Equity earnings, net of income tax: Sempra Texas Utilities 160 184 243 346 Sempra Infrastructure 75 32 79 53 235 216 322 399 Total $ 388 $ 375 $ 607 $ 701 (1) Revenues for reportable segments include intersegment revenues of $5, $28, and $19 for the three months ended June 30, 2023 and $9, $62, and $65 for the six months ended June 30, 2023; $3, $23, and $14 for the three months ended June 30, 2022 and $7, $49, and $28 for the six months ended June 30, 2022 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively. SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 184 $ 176 $ 442 $ 410 SoCalGas 155 87 515 421 Sempra Texas Utilities 160 186 243 348 Sempra Infrastructure 208 183 523 278 All other (104) (73) (151) (286) Total $ 603 $ 559 $ 1,572 $ 1,171 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,239 $ 1,090 SoCalGas 961 931 Sempra Infrastructure 2,078 336 All other 4 4 Total $ 4,282 $ 2,361 June 30, December 31, ASSETS SDG&E $ 27,786 $ 26,422 SoCalGas 22,591 22,346 Sempra Texas Utilities 13,988 13,781 Sempra Infrastructure 17,610 15,760 All other 1,773 1,376 Intersegment receivables (1,021) (1,111) Total $ 82,727 $ 78,574 EQUITY METHOD INVESTMENTS Sempra Texas Utilities $ 13,979 $ 13,772 Sempra Infrastructure 2,036 1,905 Total $ 16,015 $ 15,677

SUBSEQUENT EVENT

SUBSEQUENT EVENT	6 Months Ended
SUBSEQUENT EVENT	Jun. 30, 2023
Subsequent Events [Abstract]
SUBSEQUENT EVENT	SUBSEQUENT EVENT SEMPRA COMMON STOCK SPLIT IN THE FORM OF A STOCK DIVIDEND On August 2, 2023, Sempra’s board of directors declared a two-for-one split of Sempra’s common stock in the form of a 100% stock dividend for shareholders of record at the close of business on August 14, 2023. Each shareholder of record will receive one additional share of Sempra common stock for every then-held share of Sempra common stock, to be distributed after the close of trading on August 21, 2023. We expect Sempra’s common stock will begin trading on a post-split basis effective August 22, 2023. Sempra’s common stock will continue to have no par value with 1,125,000,000 authorized shares. The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented: PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS (Dollars in millions, except per share amounts; shares in thousands) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 630,014 629,691 629,926 631,190 Dilutive effect of stock options and RSUs 2,107 2,044 2,259 2,104 Weighted-average common shares outstanding for diluted EPS 632,121 631,735 632,185 633,294 EPS: Basic $ 0.96 $ 0.89 $ 2.50 $ 1.86 Diluted $ 0.95 $ 0.89 $ 2.49 $ 1.85 (1) Includes 710 and 798 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 716 and 806 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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. Upon the distribution date for the stock dividend, all historical shares and per share information related to issued and outstanding common stock and outstanding equity awards exercisable into common stock will be retroactively adjusted to reflect the stock split in future financial statements.

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Jun. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

GENERAL INFORMATION AND OTHER_2

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	6 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Effective May 12, 2023, our company changed its legal name from Sempra Energy to Sempra. Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities. We have four separate reportable segments, which we discuss in Note 11. 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 common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SoCalGas
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. We have eliminated intercompany accounts and transactions within Sempra’s consolidated financial statements. We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2023 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. All December 31, 2022 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2022 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes. The information contained in this report should be read in conjunction with the Annual Report.
Regulated Operations	Regulated Operations SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas.
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 sales-type leases 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 5. 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.
Variable Interest Entity Policy	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.
Earnings Per Share Policy	Basic EPS is calculated by dividing earnings attributable to common shares 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.
Interim period effective tax rate policy	Sempra, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted ETR anticipated for the full year. Unusual and infrequent items and items that cannot be reliably estimated are recorded in the interim period in which they occur, which can result in variability in the ETR.
Flow-through rate-making treatment tax policy	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 AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment. Under the IRA, beginning in 2023, the scope of projects eligible for investment tax credits was expanded to include standalone energy storage projects. The IRA also provided an election that prospectively permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset. Under this election, SDG&E recorded a regulatory liability to offset these investment tax credits, which reduced SDG&E’s and Sempra’s ETR in 2023. On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the three months and six months ended June 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. SoCalGas recorded an associated
Derivative Financial Instruments	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 of variability of future cash flows of a given revenue or expense item, 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 derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, 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 limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. 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 Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power. ▪ 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 Condensed Consolidated Statements of Operations. ▪ Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations. ▪ From time to time, our various businesses, including SDG&E and SoCalGas, may use other 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. In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap. As we discuss in Note 6, a minimum of 60% of the projected amount of term loans outstanding is required to be hedged under the Port Arthur LNG term loan facility agreement. In March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps with 17 counterparties to hedge the variability in cash flows related to the SOFR-based component of interest payments on forecasted loans outstanding under the agreement. The notional amounts of the interest rate swaps generally increase in proportion to the forecasted borrowings up to a maximum amount of $4.2 billion prior to the maturity of the term loans on March 20, 2030. Under the interest rate swaps, which are designated as cash flow hedges, Port Arthur LNG receives interest at Term SOFR and pays interest at a fixed rate of 3.23% based on amortizing notional amounts maturing in 2048. FOREIGN CURRENCY DERIVATIVES We may 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 fixed 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. CREDIT RISK RELATED 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.
Fair Value Measurement Policy	We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2022. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 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: ▪ 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 instruments 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 5, 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.”
Gains and Losses on NDTs	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 Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Legal Proceedings	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.
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 Utilitie s holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electricity 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 L.P., which owns Sharyland Utilities, L.L.C., 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. 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. 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.

GENERAL INFORMATION AND OTHER_3

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)	6 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Condensed Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Condensed Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) June 30, December 31, Cash and cash equivalents $ 1,077 $ 370 Restricted cash, current 74 40 Restricted cash, noncurrent 91 52 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 1,242 $ 462
Accounts Receivable, Allowance for Credit Loss Table	We provide below the 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. CHANGES IN ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) 2023 2022 Sempra: Allowances for credit losses at January 1 $ 181 $ 136 Provisions for expected credit losses 228 77 Write-offs (43) (36) Allowances for credit losses at June 30 $ 366 $ 177 SDG&E: Allowances for credit losses at January 1 $ 78 $ 66 Provisions for expected credit losses 63 37 Write-offs (23) (18) Allowances for credit losses at June 30 $ 118 $ 85 SoCalGas: Allowances for credit losses at January 1 $ 98 $ 69 Provisions for expected credit losses 164 37 Write-offs (20) (18) Allowances for credit losses at June 30 $ 242 $ 88 Allowances for credit losses related to trade receivables and other receivables are included in the Condensed Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) June 30, December 31, 2023 2022 Sempra: Accounts receivable – trade, net $ 320 $ 140 Accounts receivable – other, net 46 40 Other long-term assets — 1 Total allowances for credit losses $ 366 $ 181 SDG&E: Accounts receivable – trade, net $ 91 $ 52 Accounts receivable – other, net 27 25 Other long-term assets — 1 Total allowances for credit losses $ 118 $ 78 SoCalGas: Accounts receivable – trade, net $ 223 $ 83 Accounts receivable – other, net 19 15 Total allowances for credit losses $ 242 $ 98
Inventory Table	The components of inventories are as follows: INVENTORY BALANCES (Dollars in millions) Sempra SDG&E SoCalGas June 30, December 31, June 30, December 31, June 30, December 31, Natural gas $ 87 $ 106 $ 1 $ 1 $ 63 $ 74 LNG 17 62 — — — — Materials and supplies 279 235 142 133 117 85 Total $ 383 $ 403 $ 143 $ 134 $ 180 $ 159
Capitalized Financing Costs Table	The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sempra $ 110 $ 60 $ 183 $ 117 SDG&E 31 26 62 54 SoCalGas 20 17 35 35
Net Periodic Benefit Cost Table	The following tables provide the components of net periodic benefit cost. The components of net periodic benefit cost, other than the service cost component, are included in the Other Income (Expense), Net, table below. NET PERIODIC BENEFIT COST – SEMPRA (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 29 $ 42 $ 3 $ 6 Interest cost 39 29 10 7 Expected return on assets (42) (45) (18) (16) Amortization of: Prior service cost 1 2 — — Actuarial loss (gain) 2 5 (6) (3) Net periodic benefit cost (credit) 29 33 (11) (6) Regulatory adjustments 29 24 11 6 Total expense recognized $ 58 $ 57 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 57 $ 83 $ 7 $ 13 Interest cost 79 59 19 14 Expected return on assets (85) (91) (35) (32) Amortization of: Prior service cost (credit) 2 5 (1) (1) Actuarial loss (gain) 4 11 (12) (7) Net periodic benefit cost (credit) 57 67 (22) (13) Regulatory adjustments 58 (3) 22 13 Total expense recognized $ 115 $ 64 $ — $ — NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 8 $ 10 $ — $ 1 Interest cost 10 6 2 2 Expected return on assets (10) (11) (2) (3) Amortization of: Actuarial loss 1 1 — — Net periodic benefit cost 9 6 — — Regulatory adjustments 4 7 — — Total expense recognized $ 13 $ 13 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 16 $ 20 $ 1 $ 3 Interest cost 20 13 4 3 Expected return on assets (20) (22) (4) (5) Amortization of: Actuarial loss (gain) 2 1 (1) (1) Net periodic benefit cost 18 12 — — Regulatory adjustments 8 2 — — Total expense recognized $ 26 $ 14 $ — $ — NET PERIODIC BENEFIT COST – SOCALGAS (Dollars in millions) Pension PBOP Three months ended June 30, 2023 2022 2023 2022 Service cost $ 17 $ 28 $ 2 $ 5 Interest cost 26 21 7 6 Expected return on assets (31) (33) (15) (14) Amortization of: Prior service cost 1 2 — — Actuarial loss (gain) — 4 (5) (3) Net periodic benefit cost (credit) 13 22 (11) (6) Regulatory adjustments 25 17 11 6 Total expense recognized $ 38 $ 39 $ — $ — Six months ended June 30, 2023 2022 2023 2022 Service cost $ 34 $ 56 $ 5 $ 10 Interest cost 51 41 14 11 Expected return on assets (60) (64) (30) (27) Amortization of: Prior service cost (credit) 2 4 (1) (1) Actuarial loss (gain) — 8 (10) (6) Net periodic benefit cost (credit) 27 45 (22) (13) Regulatory adjustments 50 (5) 22 13 Total expense recognized $ 77 $ 40 $ — $ —
Earnings Per Share Computations Table	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 315,007 314,845 314,963 315,595 Dilutive effect of stock options and RSUs (2) 1,053 1,022 1,129 1,052 Weighted-average common shares outstanding for diluted EPS 316,060 315,867 316,092 316,647 EPS: Basic $ 1.91 $ 1.78 $ 4.99 $ 3.71 Diluted $ 1.91 $ 1.77 $ 4.97 $ 3.70 (1) Includes 355 and 399 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 358 and 403 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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. The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented: PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS (Dollars in millions, except per share amounts; shares in thousands) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 630,014 629,691 629,926 631,190 Dilutive effect of stock options and RSUs 2,107 2,044 2,259 2,104 Weighted-average common shares outstanding for diluted EPS 632,121 631,735 632,185 633,294 EPS: Basic $ 0.96 $ 0.89 $ 2.50 $ 1.86 Diluted $ 0.95 $ 0.89 $ 2.49 $ 1.85 (1) Includes 710 and 798 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 716 and 806 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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.
Schedule of Accumulated Other Comprehensive Income (Loss) Table	The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, after amounts attributable to NCI. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (Dollars in millions) Foreign Financial Pension Total Three months ended June 30, 2023 and 2022 Sempra: Balance at March 31, 2023 $ (49) $ (35) $ (98) $ (182) OCI before reclassifications 11 53 — 64 Amounts reclassified from AOCI — (4) 1 (3) Net OCI 11 49 1 61 Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) Balance at March 31, 2022 $ (76) $ (78) $ (75) $ (229) OCI before reclassifications 1 37 1 39 Amounts reclassified from AOCI (2) 10 11 2 23 Net OCI (2) 11 48 3 62 Balance at June 30, 2022 $ (65) $ (30) $ (72) $ (167) SDG&E: Balance at March 31, 2023 and June 30, 2023 $ (7) $ (7) Balance at March 31, 2022 and June 30, 2022 $ (10) $ (10) SoCalGas: Balance at March 31, 2023 $ (12) $ (11) $ (23) Amounts reclassified from AOCI 1 — 1 Net OCI 1 — 1 Balance at June 30, 2023 $ (11) $ (11) $ (22) Balance at March 31, 2022 $ (13) $ (17) $ (30) Amounts reclassified from AOCI 1 — 1 Net OCI 1 — 1 Balance at June 30, 2022 $ (12) $ (17) $ (29) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $9 of foreign currency translation adjustments associated with sale of NCI to ADIA, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss). CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (CONTINUED) (Dollars in millions) Foreign Financial Pension Total Six months ended June 30, 2023 and 2022 Sempra: Balance at December 31, 2022 $ (59) $ 10 $ (86) $ (135) OCI before reclassifications 21 13 (13) 21 Amounts reclassified from AOCI — (9) 2 (7) Net OCI 21 4 (11) 14 Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) Balance at December 31, 2021 $ (79) $ (156) $ (83) $ (318) OCI before reclassifications 4 111 7 122 Amounts reclassified from AOCI (2) 10 15 4 29 Net OCI (2) 14 126 11 151 Balance at June 30, 2022 $ (65) $ (30) $ (72) $ (167) SDG&E: Balance at December 31, 2022 and June 30, 2023 $ (7) $ (7) Balance at December 31, 2021 and June 30, 2022 $ (10) $ (10) SoCalGas: Balance at December 31, 2022 $ (12) $ (12) $ (24) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at June 30, 2023 $ (11) $ (11) $ (22) Balance at December 31, 2021 $ (13) $ (18) $ (31) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at June 30, 2022 $ (12) $ (17) $ (29) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $9 of foreign currency translation adjustments associated with sale of NCI to ADIA, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).
Reclassifications out of AOCI Table	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about AOCI Amounts reclassified Affected line item on Condensed Three months ended June 30, 2023 2022 Sempra: Foreign currency translation adjustments $ — $ 1 Operation and Maintenance Financial instruments: Interest rate instruments $ (14) $ 13 Equity Earnings (1) Foreign exchange instruments — (1) Revenues: Energy-Related Businesses 1 1 Other Income (Expense), Net Foreign exchange instruments 1 — Equity Earnings Interest rate and foreign exchange instruments (1) (1) Interest Expense Total, before income tax (13) 12 — (4) Income Tax Expense Total, net of income tax (13) 8 9 3 Earnings Attributable to Noncontrolling Interests Total, net of income tax and after NCI $ (4) $ 11 Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ 2 Other Income (Expense), Net Amortization of prior service cost — 1 Other Income (Expense), Net Total, before income tax 1 3 — (1) Income Tax Expense Total, net of income tax $ 1 $ 2 Total reclassifications for the period, net of income tax and after NCI $ (3) $ 14 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 Interest Expense Total reclassifications for the period, net of income tax $ 1 $ 1 (1) Equity earnings at our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED) (Dollars in millions) Details about AOCI Amounts reclassified Affected line item on Condensed Six months ended June 30, 2023 2022 Sempra: Foreign currency translation adjustments $ — $ 1 Operation and Maintenance Financial instruments: Interest rate instruments $ — $ (1) Interest Expense Interest rate instruments (21) 27 Equity Earnings (1) Foreign exchange instruments — (2) Revenues: Energy-Related Businesses 2 1 Other Income (Expense), Net Foreign exchange instruments 2 (1) Equity Earnings (1) Interest rate and foreign exchange instruments (1) (1) Interest Expense (6) (6) Other Income (Expense), Net Total, before income tax (24) 17 3 (5) Income Tax Expense Total, net of income tax (21) 12 12 3 Earnings Attributable to Noncontrolling Interests Total, net of income tax and after NCI $ (9) $ 15 Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ 4 Other Income (Expense), Net Amortization of prior service cost 1 2 Other Income (Expense), Net Total, before income tax 2 6 — (2) Income Tax Expense Total, net of income tax $ 2 $ 4 Total reclassifications for the period, net of income tax and after NCI $ (7) $ 20 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 Interest Expense Pension and PBOP (2) : Amortization of actuarial loss $ — $ 1 Other Income (Expense), Net Amortization of prior service cost 1 — Other Income (Expense), Net Total, net of income tax $ 1 $ 1 Total reclassifications for the period, net of income tax $ 2 $ 2 (1) Equity earnings at our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above).
Ownership Interests Held By Others Table	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 Condensed Consolidated Balance Sheets. OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by noncontrolling interests Equity held by June 30, December 31, June 30, December 31, Sempra Infrastructure: SI Partners 30.0 % 30.0 % $ 2,424 $ 2,060 SI Partners subsidiaries (1) 0.1 - 30.0 0.1 - 16.6 734 61 Total Sempra $ 3,158 $ 2,121 (1) SI Partners has subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
Transactions with Affiliates Table	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) June 30, December 31, Sempra: Tax sharing arrangement with Oncor Holdings $ 15 $ 41 Various affiliates 11 13 Total due from unconsolidated affiliates – current $ 26 $ 54 Sempra Infrastructure (1) : TAG Pipelines Norte, S. de R.L. de C.V. – 5.5% Note due January 9, 2024 $ (5) $ — Total due to unconsolidated affiliates – current $ (5) $ — Sempra Infrastructure (1) : TAG Pipelines Norte, S. de R.L. de C.V.: 5.5% Note due January 9, 2024 $ — $ (40) 5.5% Note due January 14, 2025 (23) (23) 5.5% Note due July 16, 2025 (22) (21) 5.5% Note due January 14, 2026 (19) (19) 5.5% Note due July 14, 2026 (11) (11) 5.5% Note due January 19, 2027 (14) — TAG – 5.74% Note due December 17, 2029 (193) (187) Total due to unconsolidated affiliates – noncurrent $ (282) $ (301) SDG&E: Various affiliates $ 1 $ — Total due from unconsolidated affiliates – current $ 1 $ — Sempra $ (29) $ (49) SoCalGas — (72) Various affiliates (14) (14) Total due to unconsolidated affiliates – current $ (43) $ (135) Income taxes due (to) from Sempra (2) $ (32) $ 10 SoCalGas: SDG&E $ — $ 72 Various affiliates 1 5 Total due from unconsolidated affiliates – current $ 1 $ 77 Sempra $ (36) $ (36) Total due to unconsolidated affiliates – current $ (36) $ (36) Income taxes due to Sempra (2) $ (11) $ (16) (1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding. (2) 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. Amounts include current and noncurrent income taxes due to/from Sempra. The following table summarizes income statement information from unconsolidated affiliates. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sempra: Revenues $ 11 $ 15 $ 24 $ 22 Interest income — 4 — 14 Interest expense 4 4 8 8 SDG&E: Revenues $ 6 $ 4 $ 10 $ 8 Cost of sales 27 26 57 50 SoCalGas: Revenues $ 28 $ 23 $ 62 $ 49 Cost of sales (1) 4 (4) 35 (4) (1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.
Other Income and Expense Table	Other Income (Expense), Net, consists of the following: OTHER INCOME (EXPENSE), NET (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sempra: Allowance for equity funds used during construction $ 37 $ 34 $ 70 $ 69 Investment gains (losses), net (1) 5 (34) 17 (47) (Losses) gains on interest rate and foreign exchange instruments, net (1) (1) 4 5 Foreign currency transaction gains (losses), net (2) 3 (3) 4 (22) Non-service components of net periodic benefit cost (26) (9) (51) 32 Interest on regulatory balancing accounts, net 19 4 37 5 Sundry, net (6) 8 (9) (5) Total $ 31 $ (1) $ 72 $ 37 SDG&E: Allowance for equity funds used during construction $ 23 $ 21 $ 46 $ 42 Non-service components of net periodic benefit cost (5) (2) (9) 9 Interest on regulatory balancing accounts, net 11 3 21 4 Sundry, net (7) — (8) 1 Total $ 22 $ 22 $ 50 $ 56 SoCalGas: Allowance for equity funds used during construction $ 14 $ 13 $ 24 $ 26 Non-service components of net periodic benefit cost (19) (6) (38) 26 Interest on regulatory balancing accounts, net 8 1 16 1 Sundry, net (2) (4) (9) (15) Total $ 1 $ 4 $ (7) $ 38 (1) Represents net investment gains (losses) 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 Condensed Consolidated Statements of Operations. (2) Includes losses of $11 in the six months ended June 30, 2022 from translation to U.S. dollars of a Mexican peso-denominated loan to IMG, which are offset by corresponding amounts included in Equity Earnings on the Condensed Consolidated Statement of Operations.
Income Tax Expense and Effective Income Tax Rates Table	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sempra: Income tax expense $ 175 $ 80 $ 551 $ 414 Income before income taxes and equity earnings $ 523 $ 364 $ 1,852 $ 1,029 Equity earnings, before income tax (1) 153 159 285 302 Pretax income $ 676 $ 523 $ 2,137 $ 1,331 Effective income tax rate 26 % 15 % 26 % 31 % SDG&E: Income tax expense $ 4 $ 42 $ 11 $ 106 Income before income taxes $ 188 $ 218 $ 453 $ 516 Effective income tax rate 2 % 19 % 2 % 21 % SoCalGas: Income tax (benefit) expense $ (21) $ 19 $ 73 $ 103 Income before income taxes $ 135 $ 107 $ 589 $ 525 Effective income tax rate (16) % 18 % 12 % 20 % (1) We discuss how we recognize equity earnings in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

REVENUES (Tables)

REVENUES (Tables)	6 Months Ended
REVENUES (Tables)	Jun. 30, 2023
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 Consolidating adjustments and Parent Sempra Three months ended June 30, 2023 By major service line: Utilities $ 1,400 $ 1,291 $ 19 $ (34) $ 2,676 Energy-related businesses — — 235 (19) 216 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 By market: Gas $ 252 $ 1,291 $ 167 $ (30) $ 1,680 Electric 1,148 — 87 (23) 1,212 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 Revenues from contracts with customers $ 1,400 $ 1,291 $ 254 $ (53) $ 2,892 Utilities regulatory revenues (138) 176 — — 38 Other revenues — — 406 (1) 405 Total revenues $ 1,262 $ 1,467 $ 660 $ (54) $ 3,335 Six months ended June 30, 2023 By major service line: Utilities $ 3,165 $ 5,132 $ 49 $ (72) $ 8,274 Energy-related businesses — — 547 (40) 507 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 By market: Gas $ 806 $ 5,132 $ 371 $ (65) $ 6,244 Electric 2,359 — 225 (47) 2,537 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 Revenues from contracts with customers $ 3,165 $ 5,132 $ 596 $ (112) $ 8,781 Utilities regulatory revenues (250) 129 — — (121) Other revenues — — 1,260 (25) 1,235 Total revenues $ 2,915 $ 5,261 $ 1,856 $ (137) $ 9,895 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) SDG&E SoCalGas Sempra Infrastructure Consolidating adjustments and Parent Sempra Three months ended June 30, 2022 By major service line: Utilities $ 1,250 $ 1,347 $ 20 $ (27) $ 2,590 Energy-related businesses — — 457 (14) 443 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 By market: Gas $ 159 $ 1,347 $ 340 $ (19) $ 1,827 Electric 1,091 — 137 (22) 1,206 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 Revenues from contracts with customers $ 1,250 $ 1,347 $ 477 $ (41) $ 3,033 Utilities regulatory revenues 149 154 — — 303 Other revenues — — 212 (1) 211 Total revenues $ 1,399 $ 1,501 $ 689 $ (42) $ 3,547 Six months ended June 30, 2022 By major service line: Utilities $ 2,751 $ 3,259 $ 48 $ (56) $ 6,002 Energy-related businesses — — 749 (29) 720 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 By market: Gas $ 489 $ 3,259 $ 569 $ (45) $ 4,272 Electric 2,262 — 228 (40) 2,450 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 Revenues from contracts with customers $ 2,751 $ 3,259 $ 797 $ (85) $ 6,722 Utilities regulatory revenues 93 235 — — 328 Other revenues — — 316 1 317 Total revenues $ 2,844 $ 3,494 $ 1,113 $ (84) $ 7,367
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at June 30, 2023, 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 and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2023. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2023 (excluding first six months of 2023) $ 175 $ 2 2024 300 4 2025 338 4 2026 365 4 2027 365 4 Thereafter 4,077 59 Total revenues to be recognized $ 5,620 $ 77 (1)
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 the six months ended June 30, 2023 or 2022. As we discuss in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra Infrastructure drew against and fully exhausted SEFE’s letters of credit in April 2022 due to SEFE’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance. CONTRACT LIABILITIES (Dollars in millions) 2023 2022 Sempra: Contract liabilities at January 1 $ (252) $ (278) Revenue from performance obligations satisfied during reporting period 5 86 Payments received in advance (2) (105) Contract liabilities at June 30 (1) $ (249) $ (297) SDG&E: Contract liabilities at January 1 $ (79) $ (83) Revenue from performance obligations satisfied during reporting period 2 2 Contract liabilities at June 30 (2) $ (77) $ (81) (1) Balances at June 30, 2023 include $6 in Other Current Liabilities and $243 in Deferred Credits and Other. (2) Balances at June 30, 2023 include $4 in Other Current Liabilities and $73 in Deferred Credits and Other.
Schedule of Contract Accounts Receivable	The table below shows receivable balances associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) June 30, 2023 December 31, 2022 Sempra: Accounts receivable – trade, net (1) $ 1,828 $ 2,291 Accounts receivable – other, net 14 25 Due from unconsolidated affiliates – current (2) 7 9 Other long-term assets (3) 3 9 Total $ 1,852 $ 2,334 SDG&E: Accounts receivable – trade, net (1) $ 813 $ 799 Accounts receivable – other, net 10 12 Due from unconsolidated affiliates – current (2) 6 2 Other long-term assets (3) 2 6 Total $ 831 $ 819 SoCalGas: Accounts receivable – trade, net $ 856 $ 1,295 Accounts receivable – other, net 4 13 Other long-term assets (3) 1 3 Total $ 861 $ 1,311 (1) At June 30, 2023 and December 31, 2022, includes $123 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues. (2) Amount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists. (3) In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas enrolled residential and small business customers with past-due balances in long-term repayment plans.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	6 Months Ended
REGULATORY MATTERS (Tables)	Jun. 30, 2023
Regulated Operations [Abstract]
Schedule of Regulatory Assets	REGULATORY ASSETS (LIABILITIES) (Dollars in millions) June 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ 8 $ (110) Deferred income taxes recoverable in rates 429 296 Pension and PBOP plan obligations 3 11 Removal obligations (2,371) (2,248) Environmental costs 106 107 Sunrise Powerlink fire mitigation 121 123 Regulatory balancing accounts (1)(2) : Commodity – electric 181 220 Gas transportation 7 60 Safety and reliability 158 107 Public purpose programs (109) (69) Wildfire mitigation plan 519 375 Liability insurance premium 102 99 Other balancing accounts (342) (50) Other regulatory assets, net (2) 153 137 Total SDG&E (1,035) (942) SoCalGas: Deferred income taxes recoverable in rates 241 161 Pension and PBOP plan obligations (232) (170) Employee benefit costs 24 24 Removal obligations (591) (616) Environmental costs 37 38 Regulatory balancing accounts (1)(2) : Commodity – gas, including transportation (362) (257) Safety and reliability 644 575 Public purpose programs (152) (158) Liability insurance premium 22 23 Other balancing accounts 288 115 Other regulatory assets, net (2) 280 223 Total SoCalGas 199 (42) Sempra Infrastructure: Deferred income taxes recoverable in rates 78 78 Other regulatory assets 5 — Total Sempra Infrastructure 83 78 Total Sempra $ (753) $ (906) (1) At June 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $748 and $562, respectively, and for SoCalGas was $859 and $692, 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	REGULATORY ASSETS (LIABILITIES) (Dollars in millions) June 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ 8 $ (110) Deferred income taxes recoverable in rates 429 296 Pension and PBOP plan obligations 3 11 Removal obligations (2,371) (2,248) Environmental costs 106 107 Sunrise Powerlink fire mitigation 121 123 Regulatory balancing accounts (1)(2) : Commodity – electric 181 220 Gas transportation 7 60 Safety and reliability 158 107 Public purpose programs (109) (69) Wildfire mitigation plan 519 375 Liability insurance premium 102 99 Other balancing accounts (342) (50) Other regulatory assets, net (2) 153 137 Total SDG&E (1,035) (942) SoCalGas: Deferred income taxes recoverable in rates 241 161 Pension and PBOP plan obligations (232) (170) Employee benefit costs 24 24 Removal obligations (591) (616) Environmental costs 37 38 Regulatory balancing accounts (1)(2) : Commodity – gas, including transportation (362) (257) Safety and reliability 644 575 Public purpose programs (152) (158) Liability insurance premium 22 23 Other balancing accounts 288 115 Other regulatory assets, net (2) 280 223 Total SoCalGas 199 (42) Sempra Infrastructure: Deferred income taxes recoverable in rates 78 78 Other regulatory assets 5 — Total Sempra Infrastructure 83 78 Total Sempra $ (753) $ (906) (1) At June 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $748 and $562, respectively, and for SoCalGas was $859 and $692, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.
CPUC Authorized Cost of Capital and Rate Structure	CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025 SDG&E SoCalGas Authorized weighting Return on Weighted return on rate base (1) Authorized weighting Return on Weighted 45.25 % 4.05 % 1.83 % Long-Term Debt 45.60 % 4.07 % 1.86 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 9.95 5.17 Common Equity 52.00 9.80 5.10 100.00 % 7.18 % 100.00 % 7.10 % (1) Total weighted return on rate base does not sum due to rounding differences.

INVESTMENT IN UNCONSOLIDATED EN

INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)	6 Months Ended
INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)	Jun. 30, 2023
Investments [Abstract]
Condensed Financial Statements	We provide summarized income statement information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Operating revenues $ 1,343 $ 1,293 $ 2,635 $ 2,542 Operating expenses (976) (908) (2,000) (1,805) Income from operations 367 385 635 737 Interest expense (133) (108) (256) (216) Income tax expense (43) (52) (67) (94) Net income 197 226 296 417 Noncontrolling interest held by Texas Transmission Investment LLC (40) (46) (60) (84) Earnings attributable to Sempra (1) 157 180 236 333

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	6 Months Ended
DEBT AND CREDIT FACILITIES (Tables)	Jun. 30, 2023
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	COMMITTED LINES OF CREDIT (Dollars in millions) June 30, 2023 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2027 $ 4,000 $ (813) $ — $ — $ 3,187 SDG&E October 2027 1,500 — — — 1,500 SoCalGas October 2027 1,200 (238) — — 962 SI Partners November 2024 1,000 — — — 1,000 IEnova and SI Partners September 2023 350 — (350) — — IEnova and SI Partners December 2023 150 — — — 150 IEnova and SI Partners February 2024 1,500 — (1,086) — 414 Port Arthur LNG March 2030 200 — — (15) 185 Total $ 9,900 $ (1,051) $ (1,436) $ (15) $ 7,398 UNCOMMITTED LETTERS OF CREDIT (Dollars in millions) June 30, 2023 Expiration date range Uncommitted letters of credit outstanding SDG&E January 2024 - May 2024 $ 15 SoCalGas November 2023 - October 2024 20 Sempra Infrastructure July 2023 - October 2043 311 Parent and other September 2023 - June 2024 168 Total $ 514 The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES June 30, 2023 December 31, 2022 Sempra 5.92 % 5.57 % SDG&E — 4.76 SoCalGas 5.14 4.71

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	6 Months Ended
DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	Jun. 30, 2023
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) Commodity Unit of measure June 30, 2023 December 31, 2022 Sempra: Natural gas MMBtu 380 254 Electricity MWh — 1 Congestion revenue rights MWh 35 42 SDG&E: Natural gas MMBtu 20 15 Congestion revenue rights MWh 35 42 SoCalGas: Natural gas MMBtu 271 224
Notional Amounts of Derivatives Table	The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments and the contingent interest rate swap. INTEREST RATE DERIVATIVES (Dollars in millions) June 30, 2023 December 31, 2022 Notional debt Maturities Notional debt Maturities Sempra: Cash flow hedges (1) $ 4,454 2023-2048 $ 294 2023-2034 (1) At June 30, 2023 and December 31, 2022, cash flow hedges accrued interest based on a notional of $491 and $294, respectively. The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) June 30, 2023 December 31, 2022 Notional amount Maturities Notional amount Maturities Sempra: Cross-currency swaps $ — — $ 306 2023 Other foreign currency derivatives 65 2023-2024 111 2023-2024
Derivative Instruments on the Condensed Consolidated Balance Sheets Table	DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) June 30, 2023 Current assets: Fixed-price contracts and other derivatives (1) Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ 16 $ 46 $ — $ (2) Foreign exchange instruments — — (15) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 251 35 (236) (42) Associated offsetting commodity contracts (232) (35) 232 35 Commodity contracts subject to rate recovery 20 17 (64) (17) Associated offsetting commodity contracts (12) (4) 12 4 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 43 59 (61) (18) Additional cash collateral for commodity contracts not subject to rate recovery 143 — — — Additional cash collateral for commodity contracts subject to rate recovery 70 — — — Total (2) $ 256 $ 59 $ (61) $ (18) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 18 $ 17 $ (26) $ (8) Associated offsetting commodity contracts (11) (4) 11 4 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 7 13 (5) — Additional cash collateral for commodity contracts subject to rate recovery 69 — — — Total (2) $ 76 $ 13 $ (5) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 2 $ — $ (38) $ (9) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 1 — (37) (9) Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 2 $ — $ (37) $ (9) (1) Included in Other Current Assets for SoCalGas. (2) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED) (Dollars in millions) December 31, 2022 Current assets: Fixed-price contracts and other derivatives (1) Other long-term assets Other current liabilities Deferred credits and other Sempra: Derivatives designated as hedging instruments: Interest rate instruments $ 10 $ 33 $ — $ — Foreign exchange instruments — — (7) (1) Interest rate and foreign exchange instruments — — (105) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 480 133 (399) (132) Associated offsetting commodity contracts (301) (39) 301 39 Commodity contracts subject to rate recovery 138 27 (97) (2) Associated offsetting commodity contracts (27) (2) 27 2 Interest rate instrument 33 — — — Net amounts presented on the balance sheet 333 152 (280) (94) Additional cash collateral for commodity contracts not subject to rate recovery 451 — — — Additional cash collateral for commodity contracts subject to rate recovery 18 — — — Total (2) $ 802 $ 152 $ (280) $ (94) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 107 $ 27 $ (13) $ (2) Associated offsetting commodity contracts (12) (2) 12 2 Net amounts presented on the balance sheet 95 25 (1) — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total (2) $ 112 $ 25 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 31 $ — $ (84) $ — Associated offsetting commodity contracts (15) — 15 — Net amounts presented on the balance sheet 16 — (69) — Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 17 $ — $ (69) $ — (1) Included in Other Current Assets for SoCalGas. (2) Normal purchase contracts previously measured at fair value are excluded.
Cash Flow Hedge Impact on the Condensed Consolidated Statements of Comprehensive Income Table	The following table includes the effects of derivative instruments designated as cash flow hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax gain (loss) reclassified Three months ended June 30, Three months ended June 30, 2023 2022 Location 2023 2022 Sempra: Interest rate instruments $ 94 $ 13 Interest Expense $ — $ — Interest rate instruments 41 50 Equity Earnings (1) 14 (13) Foreign exchange instruments (2) — Revenues: Energy- Related Businesses — 1 Other Income (Expense), Net (1) (1) Foreign exchange instruments (1) — Equity Earnings (1) (1) — Interest rate and foreign exchange instruments — 4 Interest Expense 1 1 Total $ 132 $ 67 $ 13 $ (12) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1) $ (1) Six months ended June 30, Six months ended June 30, 2023 2022 Location 2023 2022 Sempra: Interest rate instruments $ 17 $ 35 Interest Expense $ — $ 1 Interest rate instruments 24 144 Equity Earnings (1) 21 (27) Foreign exchange instruments (8) (3) Revenues: Energy- Related Businesses — 2 Other Income (Expense), Net (2) (1) Foreign exchange instruments (6) (2) Equity Earnings (1) (2) 1 Interest rate and foreign exchange instruments 7 13 Interest Expense 1 1 Other Income (Expense), Net 6 6 Total $ 34 $ 187 $ 24 $ (17) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1) $ (1) (1) Equity earnings at our foreign equity method investees are recognized after tax.
Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table	The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended June 30, Six months ended June 30, Location 2023 2022 2023 2022 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ 253 $ (151) $ 702 $ (228) Commodity contracts subject to rate recovery Cost of Natural Gas (20) (4) (47) (4) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (27) (24) (18) (6) Interest rate instrument Interest Expense — — (47) — Total $ 206 $ (179) $ 590 $ (238) SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ (27) $ (24) $ (18) $ (6) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (20) $ (4) $ (47) $ (4)

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
FAIR VALUE MEASUREMENTS (Tables)	Jun. 30, 2023
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures	RECURRING FAIR VALUE MEASURES – SEMPRA (Dollars in millions) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 22 $ 2 $ — $ 24 Equity securities 318 4 — 322 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 25 14 — 39 Municipal bonds — 266 — 266 Other securities — 218 — 218 Total debt securities 25 498 — 523 Total nuclear decommissioning trusts (1) 365 504 — 869 Short-term investments held in Rabbi Trust 51 — — 51 Interest rate instruments — 62 — 62 Commodity contracts not subject to rate recovery — 19 — 19 Effect of netting and allocation of collateral (2) 143 — — 143 Commodity contracts subject to rate recovery — 1 20 21 Effect of netting and allocation of collateral (2) 65 — 5 70 Support Agreement, net of related guarantee fees — — 23 23 Total $ 624 $ 586 $ 48 $ 1,258 Liabilities: Interest rate instruments $ — $ 2 $ — $ 2 Foreign exchange instruments — 15 — 15 Commodity contracts not subject to rate recovery — 11 — 11 Commodity contracts subject to rate recovery 14 51 — 65 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 79 $ — $ 79 (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 (CONTINUED) (Dollars in millions) Level 1 Level 2 Level 3 Total Fair value at December 31, 2022 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 10 $ 1 $ — $ 11 Equity securities 293 4 — 297 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 27 13 — 40 Municipal bonds — 270 — 270 Other securities — 227 — 227 Total debt securities 27 510 — 537 Total nuclear decommissioning trusts (1) 330 515 — 845 Short-term investments held in Rabbi Trust 55 — — 55 Interest rate instruments — 76 — 76 Commodity contracts not subject to rate recovery — 273 — 273 Effect of netting and allocation of collateral (2) 451 — — 451 Commodity contracts subject to rate recovery 82 19 35 136 Effect of netting and allocation of collateral (2) 12 — 6 18 Support Agreement, net of related guarantee fees — — 17 17 Total $ 930 $ 883 $ 58 $ 1,871 Liabilities: Foreign exchange instruments $ — $ 8 $ — $ 8 Interest rate and foreign exchange instruments — 105 — 105 Commodity contracts not subject to rate recovery — 191 — 191 Commodity contracts subject to rate recovery — 70 — 70 Total $ — $ 374 $ — $ 374 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) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 22 $ 2 $ — $ 24 Equity securities 318 4 — 322 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 25 14 — 39 Municipal bonds — 266 — 266 Other securities — 218 — 218 Total debt securities 25 498 — 523 Total nuclear decommissioning trusts (1) 365 504 — 869 Commodity contracts subject to rate recovery — — 20 20 Effect of netting and allocation of collateral (2) 64 — 5 69 Total $ 429 $ 504 $ 25 $ 958 Liabilities: Commodity contracts subject to rate recovery $ 14 $ 5 $ — $ 19 Effect of netting and allocation of collateral (2) (14) — — (14) Total $ — $ 5 $ — $ 5 Fair value at December 31, 2022 Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 10 $ 1 $ — $ 11 Equity securities 293 4 — 297 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 27 13 — 40 Municipal bonds — 270 — 270 Other securities — 227 — 227 Total debt securities 27 510 — 537 Total nuclear decommissioning trusts (1) 330 515 — 845 Commodity contracts subject to rate recovery 82 3 35 120 Effect of netting and allocation of collateral (2) 11 — 6 17 Total $ 423 $ 518 $ 41 $ 982 Liabilities: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Total $ — $ 1 $ — $ 1 (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) Level 1 Level 2 Level 3 Total Fair value at June 30, 2023 Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 Effect of netting and allocation of collateral (1) 1 — — 1 Total $ 1 $ 1 $ — $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 46 $ — $ 46 Total $ — $ 46 $ — $ 46 Fair value at December 31, 2022 Assets: Commodity contracts subject to rate recovery $ — $ 16 $ — $ 16 Effect of netting and allocation of collateral (1) 1 — — 1 Total $ 1 $ 16 $ — $ 17 Liabilities: Commodity contracts subject to rate recovery $ — $ 69 $ — $ 69 Total $ — $ 69 $ — $ 69 (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	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) Three months ended June 30, 2023 2022 Balance at April 1 $ 30 $ 58 Realized and unrealized losses (4) (30) Allocated transmission instruments (2) (6) Settlements (4) 11 Balance at June 30 $ 20 $ 33 Change in unrealized losses relating to instruments still held at June 30 $ (7) $ (23) Six months ended June 30, 2023 2022 Balance at January 1 $ 35 $ 54 Realized and unrealized losses (8) (23) Allocated transmission instruments (2) (6) Settlements (5) 8 Balance at June 30 $ 20 $ 33 Change in unrealized losses relating to instruments still held at June 30 $ (9) $ (18) (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) Three months ended June 30, 2023 2022 Balance at April 1 $ 24 $ 12 Realized and unrealized gains (1) 1 6 Settlements (2) (2) Balance at June 30 (2) $ 23 $ 16 Change in unrealized gains relating to instruments still held at June 30 $ 1 $ 5 Six months ended June 30, 2023 2022 Balance at January 1 $ 17 $ 7 Realized and unrealized gains (1) 10 14 Settlements (4) (5) Balance at June 30 (2) $ 23 $ 16 Change in unrealized gains relating to instruments still held at June 30 $ 9 $ 13 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Condensed Consolidated Statements of Operations. (2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet.
Schedule of Fair Value 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 2023 $ (3.09) to $ 10.71 $ (0.56) 2022 (3.67) to 6.96 (0.70) LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Weighted-average 2023 $ 22.75 to $ 117.50 $ 74.02 2022 25.25 to 125.00 66.36
Fair Value of Financial Instruments	The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Condensed Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value Level 1 Level 2 Level 3 Total June 30, 2023 Sempra: Long-term note receivable (1) $ 326 $ — $ — $ 296 $ 296 Long-term amounts due to unconsolidated affiliates 287 — 251 — 251 Total long-term debt (2) 27,419 — 24,630 — 24,630 SDG&E: Total long-term debt (3) $ 8,600 $ — $ 7,535 $ — $ 7,535 SoCalGas: Total long-term debt (4) $ 6,759 $ — $ 6,270 $ — $ 6,270 December 31, 2022 Sempra: Long-term note receivable (1) $ 318 $ — $ — $ 286 $ 286 Long-term amounts due to unconsolidated affiliates 301 — 263 — 263 Total long-term debt (2) 24,513 — 21,549 — 21,549 SDG&E: Total long-term debt (3) $ 7,800 $ — $ 6,726 $ — $ 6,726 SoCalGas: Total long-term debt (4) $ 6,059 $ — $ 5,538 $ — $ 5,538 (1) Before allowances for credit losses of $6 and $7 at June 30, 2023 and December 31, 2022, respectively. Excludes unamortized transaction costs of $4 and $5 at June 30, 2023 and December 31, 2022, respectively. (2) Before reductions of unamortized discount and debt issuance costs of $325 and $289 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,351 and $1,343 at June 30, 2023 and December 31, 2022, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $85 and $70 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,241 and $1,256 at June 30, 2023 and December 31, 2022, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $57 and $48 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $110 and $87 at June 30, 2023 and December 31, 2022, respectively.

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	6 Months Ended
SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	Jun. 30, 2023
Public Utilities, General Disclosures [Abstract]
Schedule of Nuclear Decommissioning Trusts Investments	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 Condensed Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 8. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated June 30, 2023 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 40 $ 1 $ (2) $ 39 Municipal bonds (2) 277 1 (12) 266 Other securities (3) 234 — (16) 218 Total debt securities 551 2 (30) 523 Equity securities 104 222 (4) 322 Short-term investments, primarily cash equivalents 24 — — 24 Receivables (payables), net (6) — — (6) Total $ 673 $ 224 $ (34) $ 863 December 31, 2022 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 40 $ 1 $ (1) $ 40 Municipal bonds 283 1 (14) 270 Other securities 248 — (21) 227 Total debt securities 571 2 (36) 537 Equity securities 111 194 (8) 297 Short-term investments, primarily cash equivalents 11 — — 11 Receivables (payables), net (4) — — (4) Total $ 689 $ 196 $ (44) $ 841 (1) Maturity dates are 2023-2053. (2) Maturity dates are 2023-2062. (3) Maturity dates are 2023-2072.
Schedule of Sales of Securities By Nuclear Decommissioning Trusts	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) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Proceeds from sales $ 138 $ 155 $ 294 $ 397 Gross realized gains 6 3 8 14 Gross realized losses (3) (7) (6) (11)

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	6 Months Ended
COMMITMENTS AND CONTINGENCIES (Tables)	Jun. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Schedule of Operating Lease Payments Received, Lease Income Table	We provide information below for leases for which we are the lessor. LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sales-type leases: Interest income $ 1 $ 2 $ 3 $ 4 Total revenues from sales-type leases (1) $ 1 $ 2 $ 3 $ 4 Operating leases: Fixed lease payments $ 76 $ 70 $ 156 $ 140 Variable lease payments 14 3 16 4 Total revenues from operating leases (1) $ 90 $ 73 $ 172 $ 144 Depreciation expense $ 15 $ 14 $ 30 $ 27 (1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations.
Sales-type Lease, Lease Income	We provide information below for leases for which we are the lessor. LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Sales-type leases: Interest income $ 1 $ 2 $ 3 $ 4 Total revenues from sales-type leases (1) $ 1 $ 2 $ 3 $ 4 Operating leases: Fixed lease payments $ 76 $ 70 $ 156 $ 140 Variable lease payments 14 3 16 4 Total revenues from operating leases (1) $ 90 $ 73 $ 172 $ 144 Depreciation expense $ 15 $ 14 $ 30 $ 27 (1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations.

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	6 Months Ended
SEGMENT INFORMATION (Tables)	Jun. 30, 2023
Segment Reporting [Abstract]
Segment Information	The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations. SEGMENT INFORMATION (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 REVENUES SDG&E $ 1,262 $ 1,399 $ 2,915 $ 2,844 SoCalGas 1,467 1,501 5,261 3,494 Sempra Infrastructure 660 689 1,856 1,113 Adjustments and eliminations (2) (2) (1) — Intersegment revenues (1) (52) (40) (136) (84) Total $ 3,335 $ 3,547 $ 9,895 $ 7,367 DEPRECIATION AND AMORTIZATION SDG&E $ 268 $ 244 $ 530 $ 483 SoCalGas 208 188 414 375 Sempra Infrastructure 70 67 139 132 All other 3 2 5 4 Total $ 549 $ 501 $ 1,088 $ 994 INTEREST INCOME SDG&E $ 4 $ 1 $ 5 $ 1 SoCalGas 1 1 5 1 Sempra Infrastructure 6 9 21 30 All other 6 4 10 8 Total $ 17 $ 15 $ 41 $ 40 INTEREST EXPENSE SDG&E $ 123 $ 114 $ 241 $ 220 SoCalGas 71 45 140 85 Sempra Infrastructure 25 32 120 59 All other 99 81 183 151 Intercompany eliminations (1) (1) (1) (1) Total $ 317 $ 271 $ 683 $ 514 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 4 $ 42 $ 11 $ 106 SoCalGas (21) 19 73 103 Sempra Infrastructure 201 70 531 161 All other (9) (51) (64) 44 Total $ 175 $ 80 $ 551 $ 414 EQUITY EARNINGS Equity earnings, before income tax: Sempra Texas Utilities $ 2 $ 3 $ 3 $ 5 Sempra Infrastructure 151 156 282 297 153 159 285 302 Equity earnings, net of income tax: Sempra Texas Utilities 160 184 243 346 Sempra Infrastructure 75 32 79 53 235 216 322 399 Total $ 388 $ 375 $ 607 $ 701 (1) Revenues for reportable segments include intersegment revenues of $5, $28, and $19 for the three months ended June 30, 2023 and $9, $62, and $65 for the six months ended June 30, 2023; $3, $23, and $14 for the three months ended June 30, 2022 and $7, $49, and $28 for the six months ended June 30, 2022 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively. SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 184 $ 176 $ 442 $ 410 SoCalGas 155 87 515 421 Sempra Texas Utilities 160 186 243 348 Sempra Infrastructure 208 183 523 278 All other (104) (73) (151) (286) Total $ 603 $ 559 $ 1,572 $ 1,171 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,239 $ 1,090 SoCalGas 961 931 Sempra Infrastructure 2,078 336 All other 4 4 Total $ 4,282 $ 2,361 June 30, December 31, ASSETS SDG&E $ 27,786 $ 26,422 SoCalGas 22,591 22,346 Sempra Texas Utilities 13,988 13,781 Sempra Infrastructure 17,610 15,760 All other 1,773 1,376 Intersegment receivables (1,021) (1,111) Total $ 82,727 $ 78,574 EQUITY METHOD INVESTMENTS Sempra Texas Utilities $ 13,979 $ 13,772 Sempra Infrastructure 2,036 1,905 Total $ 16,015 $ 15,677

SUBSEQUENT EVENT (Tables)

SUBSEQUENT EVENT (Tables)	6 Months Ended
SUBSEQUENT EVENT (Tables)	Jun. 30, 2023
Subsequent Events [Abstract]
Earnings Per Share Computations Table	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 315,007 314,845 314,963 315,595 Dilutive effect of stock options and RSUs (2) 1,053 1,022 1,129 1,052 Weighted-average common shares outstanding for diluted EPS 316,060 315,867 316,092 316,647 EPS: Basic $ 1.91 $ 1.78 $ 4.99 $ 3.71 Diluted $ 1.91 $ 1.77 $ 4.97 $ 3.70 (1) Includes 355 and 399 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 358 and 403 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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. The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented: PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS (Dollars in millions, except per share amounts; shares in thousands) Three months ended June 30, Six months ended June 30, 2023 2022 2023 2022 Numerator: Earnings attributable to common shares $ 603 $ 559 $ 1,572 $ 1,171 Denominator: Weighted-average common shares outstanding for basic EPS (1) 630,014 629,691 629,926 631,190 Dilutive effect of stock options and RSUs 2,107 2,044 2,259 2,104 Weighted-average common shares outstanding for diluted EPS 632,121 631,735 632,185 633,294 EPS: Basic $ 0.96 $ 0.89 $ 2.50 $ 1.86 Diluted $ 0.95 $ 0.89 $ 2.49 $ 1.85 (1) Includes 710 and 798 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 716 and 806 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. 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.

GENERAL INFORMATION AND OTHER_4

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	6 Months Ended
	Jun. 30, 2023 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

GENERAL INFORMATION AND OTHER_5

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022		Jun. 30, 2022	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 1,077	$ 370	[1]
Restricted cash, current	74	40	[1]
Restricted cash, noncurrent	91	52	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 1,242	$ 462		$ 2,093	$ 581

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_6

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022	Mar. 31, 2022
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 1,852		$ 2,334
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	181	$ 136
Provisions for expected credit losses	228	77
Write-offs	(43)	(36)
Ending balance	366	177
Allowance for credit losses	6		7
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	320		140
Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	14		25
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	46		40
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	3		9
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	0		1
Other long-term assets \| KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	6		7
Deferred Credits and Other \| Sempra LNG
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses	6		6
San Diego Gas and Electric Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	831		819
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	78	66
Provisions for expected credit losses	63	37
Write-offs	(23)	(18)
Ending balance	118	85
San Diego Gas and Electric Company \| Customers Under California Arrearage Payment Program
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			51	$ 63
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	91		52
San Diego Gas and Electric Company \| Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	10		12
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	27		25
San Diego Gas and Electric Company \| Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	2		6
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	0		1
Southern California Gas Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	861		1,311
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	98	69
Provisions for expected credit losses	164	37
Write-offs	(20)	(18)
Ending balance	242	$ 88
Southern California Gas Company \| Customers Under California Arrearage Payment Program
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			59	$ 79
Southern California Gas Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	223		83
Southern California Gas Company \| Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	4		13
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	19		15
Southern California Gas Company \| Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 1		$ 3

GENERAL INFORMATION AND OTHER_7

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Inventory [Line Items]
Natural gas	$ 87	$ 106
LNG	17	62
Materials and supplies	279	235
Total	383	403	[1]
San Diego Gas and Electric Company
Inventory [Line Items]
Natural gas	1	1
LNG	0	0
Materials and supplies	142	133
Total	143	134	[1]
Southern California Gas Company
Inventory [Line Items]
Natural gas	63	74
LNG	0	0
Materials and supplies	117	85
Total	$ 180	$ 159	[1]

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_8

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022	Nov. 30, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Loan to KKR in exchange for interest-bearing promissory note			$ 300
Compound interest rate (as a percent)	5%
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable, net	$ 324	$ 316

GENERAL INFORMATION AND OTHER_9

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 110	$ 60	$ 183	$ 117
San Diego Gas and Electric Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	31	26	62	54
Southern California Gas Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 20	$ 17	$ 35	$ 35

GENERAL INFORMATION AND OTHE_10

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PROPERTY, PLANT AND EQUIPMENT (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) segment
Property, Plant and Equipment [Line Items]
Number of reportable segments	4
Sempra Infrastructure
Property, Plant and Equipment [Line Items]
Number of reportable segments	2
Sempra Infrastructure \| Guaymas-El Oro segment of the Sonora Pipeline
Property, Plant and Equipment [Line Items]
Property, plant and equipment \| $	$ 414

GENERAL INFORMATION AND OTHE_11

GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Variable Interest Entities [Line Items]
Property plant and equipment, net	$ 51,478	$ 47,782	[1]
Finance lease obligations	1,351	1,343
Equity method investment	13,869	13,665	[1]
Assets	82,727	78,574	[1]
Oncor Holdings \| Sempra Texas Utilities
Variable Interest Entities [Line Items]
Equity method investment	13,869	13,665
Cameron LNG Holdings \| Sempra Infrastructure
Variable Interest Entities [Line Items]
Equity method investment	979	886
San Diego Gas and Electric Company
Variable Interest Entities [Line Items]
Property plant and equipment, net	22,663	21,806	[1]
Finance lease obligations	1,241	1,256
Assets	$ 27,786	26,422	[1]
IEnova \| ECA LNG JV
Variable Interest Entities [Line Items]
Ownership percentage in consolidated entity (in percentage)	83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Variable Interest Entities [Line Items]
Ownership percentage in consolidated entity (in percentage)	16.60%
Variable Interest Entity, Not Primary Beneficiary \| Sempra Infrastructure
Variable Interest Entities [Line Items]
Maximum exposure under guarantor obligations	$ 979
Variable Interest Entity, Not Primary Beneficiary \| San Diego Gas and Electric Company
Variable Interest Entities [Line Items]
Property plant and equipment, net	1,181	1,194
Finance lease obligations	1,181	1,194
Variable Interest Entity, Primary Beneficiary \| ECA LNG JV \| Sempra Infrastructure
Variable Interest Entities [Line Items]
Assets	1,330	1,099
Liabilities	900	$ 685
Variable Interest Entity, Primary Beneficiary \| Port Arthur LNG \| Sempra Infrastructure
Variable Interest Entities [Line Items]
Assets	2,690
Liabilities	$ 455

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_12

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pension
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 29	$ 42	$ 57	$ 83
Interest cost	39	29	79	59
Expected return on assets	(42)	(45)	(85)	(91)
Amortization of:
Prior service cost (credit)	1	2	2	5
Actuarial loss (gain)	2	5	4	11
Net periodic benefit cost (credit)	29	33	57	67
Regulatory adjustments	29	24	58	(3)
Total expense recognized	58	57	115	64
Pension \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	8	10	16	20
Interest cost	10	6	20	13
Expected return on assets	(10)	(11)	(20)	(22)
Amortization of:
Actuarial loss (gain)	1	1	2	1
Net periodic benefit cost (credit)	9	6	18	12
Regulatory adjustments	4	7	8	2
Total expense recognized	13	13	26	14
Pension \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	17	28	34	56
Interest cost	26	21	51	41
Expected return on assets	(31)	(33)	(60)	(64)
Amortization of:
Prior service cost (credit)	1	2	2	4
Actuarial loss (gain)	0	4	0	8
Net periodic benefit cost (credit)	13	22	27	45
Regulatory adjustments	25	17	50	(5)
Total expense recognized	38	39	77	40
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	6	7	13
Interest cost	10	7	19	14
Expected return on assets	(18)	(16)	(35)	(32)
Amortization of:
Prior service cost (credit)	0	0	(1)	(1)
Actuarial loss (gain)	(6)	(3)	(12)	(7)
Net periodic benefit cost (credit)	(11)	(6)	(22)	(13)
Regulatory adjustments	11	6	22	13
Total expense recognized	0	0	0	0
PBOP \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	1	1	3
Interest cost	2	2	4	3
Expected return on assets	(2)	(3)	(4)	(5)
Amortization of:
Actuarial loss (gain)	0	0	(1)	(1)
Net periodic benefit cost (credit)	0	0	0	0
Regulatory adjustments	0	0	0	0
Total expense recognized	0	0	0	0
PBOP \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	5	5	10
Interest cost	7	6	14	11
Expected return on assets	(15)	(14)	(30)	(27)
Amortization of:
Prior service cost (credit)	0	0	(1)	(1)
Actuarial loss (gain)	(5)	(3)	(10)	(6)
Net periodic benefit cost (credit)	(11)	(6)	(22)	(13)
Regulatory adjustments	11	6	22	13
Total expense recognized	$ 0	$ 0	$ 0	$ 0

GENERAL INFORMATION AND OTHE_13

GENERAL INFORMATION AND OTHER FINANCIAL DATA - DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Dedicated assets in support of certain benefit plans	$ 520	$ 505	[1]

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_14

GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares, basic	$ 603	$ 559	$ 1,572	$ 1,171
Earnings attributable to common shares, diluted	$ 603	$ 559	$ 1,572	$ 1,171
Weighted-average common shares outstanding for basic EPS (in shares)	315,007,000	314,845,000	314,963,000	315,595,000
Dilutive effect of stock options and RSUs (in shares)	1,053,000	1,022,000	1,129,000	1,052,000
Weighted-average common shares outstanding for diluted EPS (in shares)	316,060,000	315,867,000	316,092,000	316,647,000
Earnings per share, basic (dollars per share)	$ 1.91	$ 1.78	$ 4.99	$ 3.71
Earnings per share, diluted (in dollars per share)	$ 1.91	$ 1.77	$ 4.97	$ 3.70
Vested RSUs included in basic WASO (in shares)	355,000	399,000	358,000	403,000
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)			163,287
Performance-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			330,810
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			135,461
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	214,069	8,899	197,042	173,064

GENERAL INFORMATION AND OTHE_15

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			$ 27,115
OCI before reclassifications		$ 64	$ 39	21	$ 122
Amounts reclassified from AOCI		(3)	23	(7)	29
Net OCI		61	62	14	151
Ending balance		27,836		27,836
Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(182)	(229)	(135)	(318)
Ending balance		(121)	(167)	(121)	(167)
Foreign currency translation adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(49)	(76)	(59)	(79)
OCI before reclassifications		11	1	21	4
Amounts reclassified from AOCI		0	10	0	10
Net OCI		11	11	21	14
Ending balance		(38)	(65)	(38)	(65)
AOCI associated with noncontrolling interests			9	9
Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(35)	(78)	10	(156)
OCI before reclassifications		53	37	13	111
Amounts reclassified from AOCI		(4)	11	(9)	15
Net OCI		49	48	4	126
Ending balance		14	(30)	14	(30)
Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(98)	(75)	(86)	(83)
OCI before reclassifications		0	1	(13)	7
Amounts reclassified from AOCI		1	2	2	4
Net OCI		1	3	(11)	11
Ending balance		(97)	(72)	(97)	(72)
San Diego Gas and Electric Company
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			9,067
Ending balance		9,509		9,509
San Diego Gas and Electric Company \| Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(7)	(10)	(7)	(10)
Ending balance		(7)	(10)	(7)	(10)
San Diego Gas and Electric Company \| Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(7)	(10)	(7)	(10)
Ending balance		(7)	(10)	(7)	(10)
Southern California Gas Company
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			6,698
Amounts reclassified from AOCI		1	1	2	2
Net OCI		1	1	2	2
Ending balance		7,215		7,215
Southern California Gas Company \| Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(23)	(30)	(24)	(31)
Ending balance		(22)	(29)	(22)	(29)
Southern California Gas Company \| Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(12)	(13)	(12)	(13)
Amounts reclassified from AOCI		1	1	1	1
Net OCI		1	1	1	1
Ending balance		(11)	(12)	(11)	(12)
Southern California Gas Company \| Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(11)	(17)	(12)	(18)
Amounts reclassified from AOCI		0	0	1	1
Net OCI		0	0	1	1
Ending balance		$ (11)	$ (17)	$ (11)	$ (17)

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_16

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance	$ 1,366	$ 1,162	$ 2,575	$ 2,248
Energy-related businesses	621	654	1,742	1,037
Other Income, Net	31	(1)	72	37
Interest expense	(317)	(271)	(683)	(514)
Income before income taxes and equity earnings	523	364	1,852	1,029
Income tax benefit (expense)	(175)	(80)	(551)	(414)
Net income	736	659	1,908	1,316
Earnings Attributable to Noncontrolling Interests	(121)	(88)	(313)	(122)
Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	1	4	(7)	38
Interest expense	(71)	(45)	(140)	(85)
Income before income taxes and equity earnings	135	107	589	525
Income tax benefit (expense)	21	(19)	(73)	(103)
Net income	156	88	516	422
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	(3)	14	(7)	20
Reclassification out of Accumulated Other Comprehensive Income \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	1	2	2
Reclassification out of Accumulated Other Comprehensive Income \| Foreign currency translation adjustments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance	0	1	0	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	(13)	12	(24)	17
Income tax benefit (expense)	0	(4)	3	(5)
Net income	(13)	8	(21)	12
Earnings attributable to common shares	(4)	11	(9)	15
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income			1	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	(14)	13	(21)	27
Interest expense			0	(1)
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	1	1	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	1	0	2	(1)
Energy-related businesses	0	(1)	0	(2)
Other Income, Net	1	1	2	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net			(6)	(6)
Interest expense	(1)	(1)	(1)	(1)
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Net, Cash Flow Hedge, Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings Attributable to Noncontrolling Interests	9	3	12	3
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	1	2	1	4
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost			0	1
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of prior service cost
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	0	1	1	2
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of prior service cost \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost			1	0
Reclassification out of Accumulated Other Comprehensive Income \| Pension and PBOP
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	1	3	2	6
Income tax benefit (expense)	0	(1)	0	(2)
Net income	$ 1	$ 2	$ 2	$ 4

GENERAL INFORMATION AND OTHE_17

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS NARRATIVE (Details) - USD ($) $ / shares in Units, $ in Millions

1 Months Ended

3 Months Ended

6 Months Ended

Mar. 20, 2023

Jun. 01, 2022

Apr. 06, 2022

Jan. 11, 2022

Mar. 31, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Aug. 02, 2023

May 12, 2023

May 11, 2023

Dec. 31, 2022

Dec. 21, 2021

Oct. 01, 2021

Noncontrolling Interest [Line Items]

Common stock, shares authorized (in shares)

1,125,000,000

750,000,000

1,125,000,000

Increase in equity

$ 498

$ 7

$ 595

$ 13

Increase in shareholders' equity

$ 1,418

255

$ 1,418

Port Arthur LNG

Noncontrolling Interest [Line Items]

Increase in equity

$ 237

SI Partners

Noncontrolling Interest [Line Items]

Increase in shareholders' equity

186

Sale of noncontrolling interest, change in equity

134

Sempra Infrastructure | SI Partners

Noncontrolling Interest [Line Items]

Increase in shareholders' equity

$ 709

Sale of noncontrolling interest, change in equity

710

Sale of noncontrolling interest, transaction costs

Reduction to deferred income tax liability

300

Sale of noncontrolling interest, transaction costs reimbursed

$ 10

KKR Denali | SI Partners

Noncontrolling Interest [Line Items]

Cash consideration for minimum amount of interest transferred

$ 108

Share of development costs incurred, threshold

439

Termination fee

$ 130

Indirect Subsidiary Of SI Partners | Port Arthur LNG

Noncontrolling Interest [Line Items]

Cash consideration

265

Increase in shareholders' equity

Sale of noncontrolling interest, transaction costs

Sale of noncontrolling interest, tax impacts

Funding commitment, aggregate amount

$ 9,000

KKR | SI Partners

Noncontrolling Interest [Line Items]

Funding commitment, aggregate amount

$ 200

Funding used

$ 186

Subsequent Event

Noncontrolling Interest [Line Items]

Common stock, shares authorized (in shares)

1,125,000,000

Port Arthur LNG | Indirect Subsidiary Of SI Partners

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

30%

Funding commitment (in percent)

110%

Guaranteed funding amount (in percent)

70%

Port Arthur LNG | Minimum | KKR Denali

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

19.60%

SI Partners | Sempra Infrastructure

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

30%

SI Partners | KKR Denali

Noncontrolling Interest [Line Items]

Ownership percentage, minimum indirect interest transferred (in percent)

42%

SI Partners | Abu Dhabi Investment Authority

Noncontrolling Interest [Line Items]

Sale of noncontrolling interest (as a percent)

10%

Sale of noncontrolling interest, aggregate purchase price

$ 1,700

SI Partners | KKR

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

20%

SI Partners | Abu Dhabi Investment Authority

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

10%

SI Partners | Sempra

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

70%

SI Partners subsidiaries | Minimum | Sempra Infrastructure

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

0.10%

SI Partners subsidiaries | Maximum | Sempra Infrastructure

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

30%

16.60%

Common stock

Noncontrolling Interest [Line Items]

Share repurchase program, number of shares repurchased (in shares)

1,471,957

1,472,756

197,770

196,592

Common stock repurchased

$ 31

$ 26

Accelerated share repurchase program, prepaid amount

$ 250

$ 200

Common stock repurchased, average price (in dollars per share)

$ 169.84

$ 135.80

GENERAL INFORMATION AND OTHE_18

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 3,158	$ 2,121	[1]
SI Partners \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	30%	30%
Other noncontrolling interests	$ 2,424	$ 2,060
SI Partners subsidiaries \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 734	$ 61
SI Partners subsidiaries \| Sempra Infrastructure \| Minimum
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	0.10%	0.10%
SI Partners subsidiaries \| Sempra Infrastructure \| Maximum
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	30%	16.60%

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_19

GENERAL INFORMATION AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	$ 26	$ 54	[1]
Total due to unconsolidated affiliates – noncurrent	(282)	(301)	[1]
Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	26	54
Total due to unconsolidated affiliates – current	(5)	0	[1]
Various affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	11	13
Tax Sharing Arrangement \| Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	15	41
TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(5)	0
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	0	[1]
San Diego Gas and Electric Company \| Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	0
Total due to unconsolidated affiliates – current	(43)	(135)	[1]
San Diego Gas and Electric Company \| Various affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	0
Total due to unconsolidated affiliates – current	(14)	(14)
San Diego Gas and Electric Company \| Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(29)	(49)
Income taxes due (to) from Sempra	(32)	10
San Diego Gas and Electric Company \| Due to/from SoCalGas
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	0	(72)
Southern California Gas Company
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	77	[1]
Southern California Gas Company \| Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	77
Total due to unconsolidated affiliates – current	(36)	(36)	[1]
Southern California Gas Company \| Various affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	1	5
Southern California Gas Company \| Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(36)	(36)
Income taxes due (to) from Sempra	(11)	(16)
Southern California Gas Company \| Due to/from SDG&E
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	0	72
Sempra Infrastructure \| Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – noncurrent	$ (282)	(301)
Five Point Five Percent Note Due January 2024 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ 0	(40)
Five Point Five Percent Note Due January 2025 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (23)	(23)
Five Point Five Percent Notes Due July 2025 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (22)	(21)
Five Point Five Percent Note due January 2026 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (19)	(19)
Five Point Five Percent Note due July 2026 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (11)	(11)
Five Point Five Percent Note due January 2027 \| Sempra Infrastructure \| TAG Pipeline Norte \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (14)	0
Five Point Seven Four Percent Note December 2029 \| Sempra Infrastructure \| TAG \| Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.74%
Total due to unconsolidated affiliates – noncurrent	$ (193)	$ (187)

[1]Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_20

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Related Party Transaction [Line Items]
Revenues	$ 3,335	$ 3,547	$ 9,895	$ 7,367
Interest income	17	15	41	40
Interest expense	317	271	683	514
Related Party
Related Party Transaction [Line Items]
Revenues	11	15	24	22
Interest income	0	4	0	14
Interest expense	4	4	8	8
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Interest income	4	1	5	1
Interest expense	123	114	241	220
Operating revenues	1,262	1,399	2,915	2,844
San Diego Gas and Electric Company \| Related Party
Related Party Transaction [Line Items]
Operating revenues	6	4	10	8
Cost of sales	27	26	57	50
Southern California Gas Company
Related Party Transaction [Line Items]
Interest income	1	1	5	1
Interest expense	71	45	140	85
Operating revenues	1,467	1,501	5,261	3,494
Southern California Gas Company \| Related Party
Related Party Transaction [Line Items]
Operating revenues	28	23	62	49
Cost of sales	$ 4	$ (4)	$ 35	$ (4)

GENERAL INFORMATION AND OTHE_21

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME, NET (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Other Income [Line Items]
Allowance for equity funds used during construction	$ 37	$ 34	$ 70	$ 69
Investment gains (losses), net	5	(34)	17	(47)
(Losses) gains on interest rate and foreign exchange instruments, net	(1)	(1)	4	5
Foreign currency transaction gains (losses), net	3	(3)	4	(22)
Non-service components of net periodic benefit cost	(26)	(9)	(51)	32
Interest on regulatory balancing accounts, net	19	4	37	5
Sundry, net	(6)	8	(9)	(5)
Total	31	(1)	72	37
San Diego Gas and Electric Company
Other Income [Line Items]
Allowance for equity funds used during construction	23	21	46	42
Non-service components of net periodic benefit cost	(5)	(2)	(9)	9
Interest on regulatory balancing accounts, net	11	3	21	4
Sundry, net	(7)	0	(8)	1
Total	22	22	50	56
Southern California Gas Company
Other Income [Line Items]
Allowance for equity funds used during construction	14	13	24	26
Non-service components of net periodic benefit cost	(19)	(6)	(38)	26
Interest on regulatory balancing accounts, net	8	1	16	1
Sundry, net	(2)	(4)	(9)	(15)
Total	$ 1	$ 4	$ (7)	38
IMG
Other Income [Line Items]
Foreign currency transaction gains (losses), net				$ (11)

GENERAL INFORMATION AND OTHE_22

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 175	$ 80	$ 551	$ 414
Income before income taxes and equity earnings	523	364	1,852	1,029
Equity earnings, before income tax:	153	159	285	302
Pretax income	$ 676	$ 523	$ 2,137	$ 1,331
Effective income tax rate (as a percent)	26%	15%	26%	31%
San Diego Gas and Electric Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 4	$ 42	$ 11	$ 106
Income before income taxes and equity earnings	$ 188	$ 218	$ 453	$ 516
Effective income tax rate (as a percent)	2%	19%	2%	21%
Southern California Gas Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (21)	$ 19	$ 73	$ 103
Income before income taxes and equity earnings	$ 135	$ 107	$ 589	$ 525
Effective income tax rate (as a percent)	(16.00%)	18%	12%	20%

GENERAL INFORMATION AND OTHE_23

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES NARRATIVE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ 175	$ 80	$ 551	$ 414
Deferred income tax liability for foreign earnings		120		120
Southern California Gas Company
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	(21)	$ 19	73	$ 103
Southern California Gas Company \| Cumulative Effect, Period of Adoption, Adjustment [Member]
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (43)		$ (43)

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,892	$ 3,033	$ 8,781	$ 6,722
Utilities regulatory revenues	38	303	(121)	328
Other revenues	405	211	1,235	317
Total revenues	3,335	3,547	9,895	7,367
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,676	2,590	8,274	6,002
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	216	443	507	720
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,680	1,827	6,244	4,272
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,212	1,206	2,537	2,450
Operating Segments \| San Diego Gas and Electric Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,400	1,250	3,165	2,751
Utilities regulatory revenues	(138)	149	(250)	93
Other revenues	0	0	0	0
Total revenues	1,262	1,399	2,915	2,844
Operating Segments \| San Diego Gas and Electric Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,400	1,250	3,165	2,751
Operating Segments \| San Diego Gas and Electric Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| San Diego Gas and Electric Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	252	159	806	489
Operating Segments \| San Diego Gas and Electric Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,148	1,091	2,359	2,262
Operating Segments \| Southern California Gas Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,291	1,347	5,132	3,259
Utilities regulatory revenues	176	154	129	235
Other revenues	0	0	0	0
Total revenues	1,467	1,501	5,261	3,494
Operating Segments \| Southern California Gas Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,291	1,347	5,132	3,259
Operating Segments \| Southern California Gas Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Southern California Gas Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,291	1,347	5,132	3,259
Operating Segments \| Southern California Gas Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	254	477	596	797
Utilities regulatory revenues	0	0	0	0
Other revenues	406	212	1,260	316
Total revenues	660	689	1,856	1,113
Operating Segments \| Sempra Infrastructure \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	19	20	49	48
Operating Segments \| Sempra Infrastructure \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	235	457	547	749
Operating Segments \| Sempra Infrastructure \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	167	340	371	569
Operating Segments \| Sempra Infrastructure \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	87	137	225	228
Consolidation, Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(53)	(41)	(112)	(85)
Utilities regulatory revenues	0	0	0	0
Other revenues	(1)	(1)	(25)	1
Total revenues	(54)	(42)	(137)	(84)
Consolidation, Eliminations \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(34)	(27)	(72)	(56)
Consolidation, Eliminations \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(19)	(14)	(40)	(29)
Consolidation, Eliminations \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(30)	(19)	(65)	(45)
Consolidation, Eliminations \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (23)	$ (22)	$ (47)	$ (40)

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Jun. 30, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 5,620
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 175
Revenues to be recognized, period of recognition	6 months
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	$ 300
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	$ 338
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	$ 365
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	$ 365
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,077
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 77
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 2
Revenues to be recognized, period of recognition	6 months
San Diego Gas and Electric Company \| 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 \| 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 \| 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 \| 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
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 59
Revenues to be recognized, period of recognition

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (252)	$ (278)
Revenue from performance obligations satisfied during reporting period	5	86
Payments received in advance	(2)	(105)
Contract liabilities, closing balance	(249)	(297)
Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(6)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(243)
San Diego Gas and Electric Company
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(79)	(83)
Revenue from performance obligations satisfied during reporting period	2	2
Contract liabilities, closing balance	(77)	$ (81)
San Diego Gas and Electric Company \| Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(4)
San Diego Gas and Electric Company \| Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ (73)

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,852	$ 2,334
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,828	2,291
Accounts receivable – trade, net \| Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	123	72
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	14	25
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	7	9
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	3	9
San Diego Gas and Electric Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	831	819
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	813	799
San Diego Gas and Electric Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	10	12
San Diego Gas and Electric Company \| Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	2
San Diego Gas and Electric Company \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	6
Southern California Gas Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	861	1,311
Southern California Gas Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	856	1,295
Southern California Gas Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	4	13
Southern California Gas Company \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1	$ 3

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (753)	$ (906)
San Diego Gas and Electric Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	748	562
San Diego Gas and Electric Company \| Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	8	(110)
San Diego Gas and Electric Company \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	429	296
San Diego Gas and Electric Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	3	11
San Diego Gas and Electric Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,371)	(2,248)
San Diego Gas and Electric Company \| Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	106	107
San Diego Gas and Electric Company \| Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	121	123
San Diego Gas and Electric Company \| Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	181	220
San Diego Gas and Electric Company \| Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	7	60
San Diego Gas and Electric Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	158	107
San Diego Gas and Electric Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(109)	(69)
San Diego Gas and Electric Company \| Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	519	375
San Diego Gas and Electric Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	102	99
San Diego Gas and Electric Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(342)	(50)
San Diego Gas and Electric Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	153	137
San Diego Gas and Electric Company \| Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,035)	(942)
Southern California Gas Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	859	692
Southern California Gas Company \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	241	161
Southern California Gas Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(232)	(170)
Southern California Gas Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(591)	(616)
Southern California Gas Company \| Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	24	24
Southern California Gas Company \| Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	37	38
Southern California Gas Company \| Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(362)	(257)
Southern California Gas Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	644	575
Southern California Gas Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(152)	(158)
Southern California Gas Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	22	23
Southern California Gas Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	288	115
Southern California Gas Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	280	223
Southern California Gas Company \| Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	199	(42)
Sempra Infrastructure \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	78	78
Sempra Infrastructure \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	5	0
Sempra Infrastructure \| Total Sempra Infrastructure
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 83	$ 78

REGULATORY MATTERS - GENERAL RA

REGULATORY MATTERS - GENERAL RATE CASE (Details) - 2024 GRC - 2024 Requirement - General Rate Case $ in Billions	1 Months Ended
	May 31, 2022 USD ($)
San Diego Gas and Electric Company
General Rate Case [Line Items]
Requested revenue requirements	$ 3
San Diego Gas and Electric Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases	8%
San Diego Gas and Electric Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases	11%
Southern California Gas Company
General Rate Case [Line Items]
Requested revenue requirements	$ 4.4
Southern California Gas Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases	6%
Southern California Gas Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases	8%

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL & FERC (Details) - California Public Utilities Commission - Forecast	36 Months Ended
	Dec. 31, 2025
San Diego Gas and Electric Company
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)	100%
Weighted return on rate base (as a percent)	7.18%
San Diego Gas and Electric Company \| Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	45.25%
San Diego Gas and Electric Company \| Authorized Weighting \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	2.75%
San Diego Gas and Electric Company \| Authorized Weighting \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	52%
San Diego Gas and Electric Company \| Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	4.05%
San Diego Gas and Electric Company \| Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	6.22%
San Diego Gas and Electric Company \| Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	9.95%
San Diego Gas and Electric Company \| Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	1.83%
San Diego Gas and Electric Company \| Weighted Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.17%
San Diego Gas and Electric Company \| Weighted Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	5.17%
Southern California Gas Company
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)	100%
Weighted return on rate base (as a percent)	7.10%
Southern California Gas Company \| Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	45.60%
Southern California Gas Company \| Authorized Weighting \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	2.40%
Southern California Gas Company \| Authorized Weighting \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	52%
Southern California Gas Company \| Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	4.07%
Southern California Gas Company \| Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	6%
Southern California Gas Company \| Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	9.80%
Southern California Gas Company \| Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	1.86%
Southern California Gas Company \| Weighted Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.14%
Southern California Gas Company \| Weighted Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	5.10%

REGULATORY MATTERS - FERC RATE

REGULATORY MATTERS - FERC RATE MATTERS (Details) - San Diego Gas and Electric Company	6 Months Ended
	Jun. 30, 2023
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (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%

INVESTMENTS IN UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		6 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) projectOwner bank	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 402	$ 403
Oncor Holdings \| Oncor Electric Delivery Company LLC.
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			80.25%
Sempra Texas Intermediate Holding Company LLC \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			100%
Sempra Texas Utilities \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Investments made during period			$ 178	171
Proceeds from distributions received			$ 204	170
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity (in percentage)			50.20%
Sempra Infrastructure \| TAG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 36	32
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			23
Sempra Infrastructure \| Other current assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			7
Sempra Infrastructure \| Other long-term assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			16
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Investments made during period			6	10
Proceeds from distributions received			$ 198	$ 233
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of project owners \| projectOwner		4
Proceeds from related party debt		$ 1,500
Number of project owners sending direct proceeds \| projectOwner		2
Number of project owners sending proceeds from external lenders \| projectOwner		2
Liability cap (as a percent)			130%
Liability cap, amount			$ 979
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related party debt		$ 753
Return on investments		$ 753
Number of banks \| bank		8
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received	$ 165
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Deferred Credits and Other
Schedule of Equity Method Investments [Line Items]
Senior note, liability	$ 22
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Other current liabilities
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 20

INVESTMENTS IN UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Schedule of Equity Method Investments [Line Items]
Net income	$ 736	$ 659	$ 1,908	$ 1,316
Equity Method Investment, Nonconsolidated Investee or Group of Investees \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,343	1,293	2,635	2,542
Operating expenses	(976)	(908)	(2,000)	(1,805)
Operating income	367	385	635	737
Interest expense	(133)	(108)	(256)	(216)
Income tax expense	(43)	(52)	(67)	(94)
Net income	197	226	296	417
Noncontrolling interest held by Texas Transmission Investment LLC	(40)	(46)	(60)	(84)
Earnings attributable to Sempra Energy	$ 157	$ 180	$ 236	$ 333

DEBT AND CREDIT FACILITIES - NA

DEBT AND CREDIT FACILITIES - NARRATIVE (Details)		1 Months Ended					6 Months Ended
DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	Mar. 20, 2023 USD ($)	Jun. 30, 2023 USD ($) bank	May 31, 2023 USD ($)	Mar. 31, 2023 USD ($)	Aug. 31, 2022 USD ($)	Jul. 31, 2022 USD ($)	Jun. 30, 2023 USD ($) bank lineOfCredit	Jun. 30, 2022 USD ($)	Mar. 21, 2023 USD ($)	Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 9,900,000,000					$ 9,900,000,000
Primary committed lines of credit \| lineOfCredit							8
Uncommitted letters of credit outstanding		514,000,000					$ 514,000,000
Issuances of debt (maturities greater than 90 days)							5,614,000,000	$ 4,818,000,000
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Amount available		32,000,000					32,000,000
Five Point Four Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 550,000,000					$ 550,000,000
Stated rate of debt (as a percent)		5.40%					5.40%
Proceeds from debt issuance		$ 545,000,000
Unamortized debt issuance costs		5,000,000					$ 5,000,000
Five Point Five Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 700,000,000					$ 700,000,000
Stated rate of debt (as a percent)		5.50%					5.50%
Proceeds from debt issuance		$ 692,000,000
Unamortized debt issuance costs		$ 8,000,000					$ 8,000,000
Sempra U.S.
Line of Credit Facility [Line Items]
Maximum ratio of indebtedness to total capitalization (as a percent)		65%					65%
SI Partners
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,000,000,000					$ 1,000,000,000
Maximum adjustment EBITDA allowed		5.25					5.25
SI Partners \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)	70%
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 200,000,000					$ 200,000,000
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Term of debt instrument (in years)				7 years
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000					$ 1,500,000,000
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate							1.05%
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Variable percentage rate		1.05%
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate		1.15%
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,200,000,000					$ 1,200,000,000
Issuances of debt (maturities greater than 90 days)							997,000,000	697,000,000
Debt issuance costs							9,000,000	6,000,000
Southern California Gas Company \| Term Loan Due 2023
Line of Credit Facility [Line Items]
Issuances of debt (maturities greater than 90 days)					$ 800,000,000
Southern California Gas Company \| Term Loan Due 2023 \| Secured Debt
Line of Credit Facility [Line Items]
Term of debt instrument (in years)						364 days
Variable percentage rate						0.70%
Debt amount						$ 800,000,000
Southern California Gas Company \| Five Point Two Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.20%
Proceeds from debt issuance			$ 495,000,000
Unamortized debt issuance costs			5,000,000
Southern California Gas Company \| Five Point Seven Five Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.75%
Proceeds from debt issuance			$ 493,000,000
Unamortized debt issuance costs			$ 7,000,000
Southern California Gas Company \| Senior Unsecured Floating Rate Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount		300,000,000					300,000,000
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000					1,500,000,000
Issuances of debt (maturities greater than 90 days)							792,000,000	1,395,000,000
Debt issuance costs							$ 9,000,000	$ 9,000,000
San Diego Gas and Electric Company \| Five Point Three Five Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount				$ 800,000,000
Stated rate of debt (as a percent)				5.35%
Proceeds from debt issuance				$ 783,000,000
Unamortized debt issuance costs				$ 17,000,000
Sempra LNG \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Term of debt instrument (in years)							5 years
Number of banks in syndicate \| bank		7					7
Weighted average interest rate (as a percent)		8.20%					8.20%			7.54%
Sempra Infrastructure \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,300,000,000					$ 1,300,000,000
Debt outstanding		708,000,000					$ 708,000,000			$ 575,000,000
IEnova \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							16.60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)	60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable
Line of Credit Facility [Line Items]
Term of debt instrument (in years)				20 years
Debt amount		6,800,000,000					$ 6,800,000,000
Debt outstanding		$ 228,000,000					$ 228,000,000
Weighted average interest rate (as a percent)		5.58%					5.58%
Upfront equity funding amount				$ 4,700,000,000					$ 4,700,000,000
Debt issuance costs				$ 200,000,000
Commitment fee (in percent)				30%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)				60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, Before Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate				2%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, After Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate				2.25%
SI Partners and ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Equity funding provided	$ 2,800,000,000
ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)	30%
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 4,000,000,000					$ 4,000,000,000

DEBT AND CREDIT FACILITIES - CO

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details) $ in Millions	Jun. 30, 2023 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900
Line of credit outstanding	(1,436)
Available unused credit	7,398
Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	(15)
Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(1,051)
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity	4,000
Line of credit outstanding	0
Available unused credit	3,187
Sempra \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Sempra \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(813)
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Line of credit outstanding	0
Available unused credit	1,500
San Diego Gas and Electric Company \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
San Diego Gas and Electric Company \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,200
Line of credit outstanding	0
Available unused credit	962
Southern California Gas Company \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Southern California Gas Company \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(238)
SI Partners
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,000
Line of credit outstanding	0
Available unused credit	1,000
SI Partners \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due September 2023
Line of Credit Facility [Line Items]
Maximum borrowing capacity	350
Line of credit outstanding	(350)
Available unused credit	0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due September 2023 \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due December 2023
Line of Credit Facility [Line Items]
Maximum borrowing capacity	150
Line of credit outstanding	0
Available unused credit	150
IEnova And SI Partners \| IEnova Committed Line Of Credit Due December 2023 \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Line of credit outstanding	(1,086)
Available unused credit	414
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| Letter of Credit
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| Commercial paper \| IEnova Committed Line Of Credit Due September 2023
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| Commercial paper \| IEnova Committed Line Of Credit Due December 2023
Line of Credit Facility [Line Items]
Line of credit outstanding	0
IEnova And SI Partners \| Commercial paper \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	200
Line of credit outstanding	0
Available unused credit	185
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	200
Line of credit outstanding	(15)
Port Arthur LNG \| Commercial paper \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Line of credit outstanding	$ 0

DEBT AND CREDIT FACILITIES - UN

DEBT AND CREDIT FACILITIES - UNCOMMITTED LETTERS OF CREDIT (Details) $ in Millions	Jun. 30, 2023 USD ($)
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 514
Letter of Credit
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	514
Letter of Credit \| San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	15
Letter of Credit \| Southern California Gas Company
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	20
Letter of Credit \| Sempra Infrastructure
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	311
Letter of Credit \| Parent and Other
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 168

DEBT AND CREDIT FACILITIES - WE

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Jun. 30, 2023	Dec. 31, 2022
Sempra
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.92%	5.57%
San Diego Gas and Electric Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0%	4.76%
Southern California Gas Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.14%	4.71%

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2023 MWh MMBTU	Dec. 31, 2022 MMBTU MWh
Natural gas \| Long
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	380	254
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	35	42
SDG&E \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	20	15
SDG&E \| Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	35	42
SoCalGas \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	271	224

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES (Details) $ in Millions		1 Months Ended	6 Months Ended
	Mar. 20, 2023	Mar. 31, 2023 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Mar. 21, 2023 counterparty	Dec. 31, 2022 USD ($)
Derivative [Line Items]
Cash paid to settle			$ 99	$ 0
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Derivative [Line Items]
Minimum amount of the projected amount of term loans (in percent)	60%
Interest Rate Swap \| Cash Flow Hedging
Derivative [Line Items]
Amount of interest rate swap						$ 3,500
Interest rate swap tenor (in years)			25 years
Notional amounts			$ 491			$ 294
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG
Derivative [Line Items]
Cash paid to settle		$ 14
Number of counterparties \| counterparty					17
Fixed rate (in percent)			3.23%
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG \| Maximum
Derivative [Line Items]
Notional amounts			$ 4,200

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Interest rate and foreign exchange instruments
Derivative [Line Items]
Notional amount of derivative	$ 0	$ 306
Foreign exchange instruments
Derivative [Line Items]
Notional amount of derivative	65	111
Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Notional amount of derivative	4,454	294
Cash Flow Hedging \| Interest Rate Swap
Derivative [Line Items]
Notional amounts	$ 491	$ 294

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 43	$ 333
Additional cash collateral for commodity contracts not subject to rate recovery	143	451
Additional cash collateral for commodity contracts subject to rate recovery	70	18
Total	256	802
Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	59	152
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	59	152
Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(61)	(280)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(61)	(280)
Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(18)	(94)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(18)	(94)
Derivatives designated as hedging instruments: \| Other current assets
Derivatives designated as hedging instruments:
Interest rate instruments	16	10
Foreign exchange instruments	0	0
Interest rate and foreign exchange instruments		0
Derivatives designated as hedging instruments: \| Other long-term assets
Derivatives designated as hedging instruments:
Interest rate instruments	46	33
Foreign exchange instruments	0	0
Interest rate and foreign exchange instruments		0
Derivatives designated as hedging instruments: \| Other current liabilities
Derivatives designated as hedging instruments:
Interest rate instruments	0	0
Foreign exchange instruments	(15)	(7)
Interest rate and foreign exchange instruments		(105)
Derivatives designated as hedging instruments: \| Deferred credits and other
Derivatives designated as hedging instruments:
Interest rate instruments	(2)	0
Foreign exchange instruments	0	(1)
Interest rate and foreign exchange instruments		0
Derivatives not designated as hedging instruments: \| Other current assets
Derivatives designated as hedging instruments:
Interest rate instruments		33
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	251	480
Associated offsetting commodity contracts	(232)	(301)
Commodity contracts subject to rate recovery	20	138
Associated offsetting commodity contracts	(12)	(27)
Associated offsetting cash collateral	0
Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	35	133
Associated offsetting commodity contracts	(35)	(39)
Commodity contracts subject to rate recovery	17	27
Associated offsetting commodity contracts	(4)	(2)
Associated offsetting cash collateral	0
Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(236)	(399)
Associated offsetting commodity contracts	232	301
Commodity contracts subject to rate recovery	(64)	(97)
Associated offsetting commodity contracts	12	27
Associated offsetting cash collateral	10
Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(42)	(132)
Associated offsetting commodity contracts	35	39
Commodity contracts subject to rate recovery	(17)	(2)
Associated offsetting commodity contracts	4	2
Associated offsetting cash collateral	4
San Diego Gas and Electric Company \| Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	7	95
Additional cash collateral for commodity contracts subject to rate recovery	69	17
Total	76	112
San Diego Gas and Electric Company \| Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	13	25
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	13	25
San Diego Gas and Electric Company \| Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(5)	(1)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(5)	(1)
San Diego Gas and Electric Company \| Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other current assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	18	107
Associated offsetting commodity contracts	(11)	(12)
Associated offsetting cash collateral	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	17	27
Associated offsetting commodity contracts	(4)	(2)
Associated offsetting cash collateral	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(26)	(13)
Associated offsetting commodity contracts	11	12
Associated offsetting cash collateral	10
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(8)	(2)
Associated offsetting commodity contracts	4	2
Associated offsetting cash collateral	4
Southern California Gas Company \| Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	1	16
Additional cash collateral for commodity contracts subject to rate recovery	1	1
Total	2	17
Southern California Gas Company \| Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
Southern California Gas Company \| Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(37)	(69)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(37)	(69)
Southern California Gas Company \| Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(9)	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(9)	0
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other current assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	2	31
Associated offsetting commodity contracts	(1)	(15)
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	0	0
Associated offsetting commodity contracts	0	0
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(38)	(84)
Associated offsetting commodity contracts	1	15
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(9)	0
Associated offsetting commodity contracts	$ 0	$ 0

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 101	$ 63	$ 6	$ 161
Pretax gain (loss) on derivatives recognized in earnings	(1)	(1)	$ 4	$ 5
Natural gas
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]			Cost of Goods and Services Sold	Cost of Goods and Services Sold
Electric fuel and purchased power
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]			Cost of Goods and Services Sold	Cost of Goods and Services Sold
Commodity contracts not subject to rate recovery
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]			Unregulated Operating Revenue	Unregulated Operating Revenue
Contingent Interest Rate Derivative
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]			INTEREST EXPENSE	INTEREST EXPENSE
Derivatives designated as hedging instruments: \| Cash Flow Hedging
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	132	67	$ 34	$ 187
Pretax gain (loss) reclassified from AOCI into earnings	13	(12)	24	(17)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	94	13	17	35
Pretax gain (loss) reclassified from AOCI into earnings	0	0	0	1
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments \| Southern California Gas Company
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	0
Pretax gain (loss) reclassified from AOCI into earnings	(1)	(1)	(1)	(1)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	4	7	13
Pretax gain (loss) reclassified from AOCI into earnings	1	1	1	1
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	41	50	24	144
Pretax gain (loss) reclassified from AOCI into earnings	14	(13)	21	(27)
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	(1)	0	(6)	(2)
Pretax gain (loss) reclassified from AOCI into earnings	(1)	0	(2)	1
Derivatives designated as hedging instruments: \| Revenues: Energy- Related Businesses \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	(2)	0	(8)	(3)
Pretax gain (loss) reclassified from AOCI into earnings	0	1	0	2
Derivatives designated as hedging instruments: \| Other Income (Expense), Net \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	(1)	(1)	(2)	(1)
Derivatives designated as hedging instruments: \| Other Income (Expense), Net \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings			6	6
Derivatives not designated as hedging instruments:
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	206	(179)	590	(238)
Derivatives not designated as hedging instruments: \| Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	253	(151)	702	(228)
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| Southern California Gas Company
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(20)	(4)	(47)	(4)
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| San Diego Gas and Electric Company
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(27)	(24)	(18)	(6)
Derivatives not designated as hedging instruments: \| Contingent Interest Rate Derivative
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	(47)	0
Derivatives not designated as hedging instruments: \| Cost of Electric Fuel and Purchased Power \| Commodity contracts subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(27)	(24)	(18)	(6)
Derivatives not designated as hedging instruments: \| Cost of Natural Gas \| Commodity contracts subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	$ (20)	$ (4)	$ (47)	$ (4)

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 23
Cash flow hedge gain (loss) to be reclassified, NCI	$ 14
Term of interest rate cash flow hedge (in years)	25 years
Southern California Gas Company
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee
Derivative [Line Items]
Term of interest rate cash flow hedge (in years)	16 years

DERIVATIVE FINANCIAL INSTRUME_9

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Derivative [Line Items]
Derivative fair value	$ 50	$ 106
Collateral	50
Southern California Gas Company
Derivative [Line Items]
Derivative fair value	46	$ 69
Collateral	$ 46

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 869	$ 845
Short-term investments held in Rabbi Trust	51	55
Support Agreement, net of related guarantee fees	23	17
Total	1,258	1,871
Total	79	374
Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	322	297
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	39	40
Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	266	270
Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	218	227
Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	523	537
Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	62	76
Derivative liabilities	2
Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	273
Effect of netting and allocation of collateral	143	451
Derivative liabilities	11	191
Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	21	136
Effect of netting and allocation of collateral	70	18
Derivative liabilities	65	70
Effect of netting and allocation of collateral	(14)
Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	15	8
Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		105
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	365	330
Short-term investments held in Rabbi Trust	51	55
Support Agreement, net of related guarantee fees	0	0
Total	624	930
Total	0	0
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	22	10
Level 1 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	318	293
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	25	27
Level 1 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 1 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 1 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	25	27
Level 1 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0
Level 1 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	143	451
Derivative liabilities	0	0
Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	82
Effect of netting and allocation of collateral	65	12
Derivative liabilities	14	0
Effect of netting and allocation of collateral	(14)
Level 1 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Level 1 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	504	515
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	586	883
Total	79	374
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	2	1
Level 2 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	4	4
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	14	13
Level 2 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	266	270
Level 2 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	218	227
Level 2 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	498	510
Level 2 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	62	76
Derivative liabilities	2
Level 2 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	273
Effect of netting and allocation of collateral	0	0
Derivative liabilities	11	191
Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	19
Effect of netting and allocation of collateral	0	0
Derivative liabilities	51	70
Effect of netting and allocation of collateral	0
Level 2 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	15	8
Level 2 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		105
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	23	17
Total	48	58
Total	0	0
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
Level 3 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
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
Level 3 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0
Level 3 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	0
Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	35
Effect of netting and allocation of collateral	5	6
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0
Level 3 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Level 3 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
San Diego Gas and Electric Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	869	845
Total	958	982
Total	5	1
San Diego Gas and Electric Company \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
San Diego Gas and Electric Company \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	322	297
San Diego Gas and Electric Company \| 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	39	40
San Diego Gas and Electric Company \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	266	270
San Diego Gas and Electric Company \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	218	227
San Diego Gas and Electric Company \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	523	537
San Diego Gas and Electric Company \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	120
Effect of netting and allocation of collateral	69	17
Derivative liabilities	19	1
Effect of netting and allocation of collateral	(14)
San Diego Gas and Electric Company \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	365	330
Total	429	423
Total	0	0
San Diego Gas and Electric Company \| 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	22	10
San Diego Gas and Electric Company \| Level 1 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	318	293
San Diego Gas and Electric Company \| 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	25	27
San Diego Gas and Electric Company \| Level 1 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 1 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 1 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	25	27
San Diego Gas and Electric Company \| Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	82
Effect of netting and allocation of collateral	64	11
Derivative liabilities	14	0
Effect of netting and allocation of collateral	(14)
San Diego Gas and Electric Company \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	504	515
Total	504	518
Total	5	1
San Diego Gas and Electric Company \| 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	2	1
San Diego Gas and Electric Company \| Level 2 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	4	4
San Diego Gas and Electric Company \| 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	14	13
San Diego Gas and Electric Company \| Level 2 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	266	270
San Diego Gas and Electric Company \| Level 2 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	218	227
San Diego Gas and Electric Company \| Level 2 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	498	510
San Diego Gas and Electric Company \| Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	3
Effect of netting and allocation of collateral	0	0
Derivative liabilities	5	1
Effect of netting and allocation of collateral	0
San Diego Gas and Electric Company \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Total	25	41
Total	0	0
San Diego Gas and Electric Company \| 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
San Diego Gas and Electric Company \| Level 3 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| 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
San Diego Gas and Electric Company \| Level 3 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	35
Effect of netting and allocation of collateral	5	6
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0
Southern California Gas Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	2	17
Total	46	69
Southern California Gas Company \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	16
Effect of netting and allocation of collateral	1	1
Derivative liabilities	46	69
Southern California Gas Company \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	1	1
Total	0	0
Southern California Gas Company \| Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	1	1
Derivative liabilities	0	0
Southern California Gas Company \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	1	16
Total	46	69
Southern California Gas Company \| Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	16
Effect of netting and allocation of collateral	0	0
Derivative liabilities	46	69
Southern California Gas Company \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	0
Total	0	0
Southern California Gas Company \| Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	$ 0	$ 0

FAIR VALUE MEASUREMENTS - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023 USD ($) $ / MWh	Jun. 30, 2022 USD ($) $ / MWh	Jun. 30, 2023 USD ($) $ / MWh	Jun. 30, 2022 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 30	$ 58	$ 35	$ 54
Realized and unrealized losses	(4)	(30)	(8)	(23)
Allocated transmission instruments	(2)	(6)	(2)	(6)
Settlements	(4)	11	(5)	8
Ending balance	20	33	20	33
Change in unrealized losses relating to instruments still held at June 30	(7)	(23)	(9)	(18)
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	24	12	17	7
Realized and unrealized gains	1	6	10	14
Settlements	(2)	(2)	(4)	(5)
Ending balance	23	16	23	16
Change in unrealized gains (losses) relating to instruments still held at the end of the period	1	5	9	13
Sempra Infrastructure \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Sempra Infrastructure \| Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	16		16
San Diego Gas and Electric Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	30	58	35	54
Realized and unrealized losses	(4)	(30)	(8)	(23)
Allocated transmission instruments	(2)	(6)	(2)	(6)
Settlements	(4)	11	(5)	8
Ending balance	20	33	20	33
Change in unrealized losses relating to instruments still held at June 30	$ (7)	$ (23)	$ (9)	$ (18)
Level 3 \| San Diego Gas and Electric Company \| Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(3.09)	(3.67)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	22.75	25.25	22.75	25.25
Level 3 \| San Diego Gas and Electric Company \| Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			10.71	6.96
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	117.50	125	117.50	125
Level 3 \| San Diego Gas and Electric Company \| Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(0.56)	(0.70)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	74.02	66.36	74.02	66.36

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Allowance for credit losses	$ 6	$ 7
Unamortized transaction costs	4	5
Unamortized discount and debt issuance costs	325	289
Finance lease obligations	1,351	1,343
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	326	318
Long-term amounts due to unconsolidated affiliates	287	301
Total long-term debt	27,419	24,513
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	296	286
Long-term amounts due to unconsolidated affiliates	251	263
Total long-term debt	24,630	21,549
Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliates	251	263
Total long-term debt	24,630	21,549
Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	296	286
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
San Diego Gas and Electric Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	85	70
Finance lease obligations	1,241	1,256
San Diego Gas and Electric Company \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,600	7,800
San Diego Gas and Electric Company \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,535	6,726
San Diego Gas and Electric Company \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
San Diego Gas and Electric Company \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,535	6,726
San Diego Gas and Electric Company \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	57	48
Finance lease obligations	110	87
Southern California Gas Company \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,759	6,059
Southern California Gas Company \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,270	5,538
Southern California Gas Company \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,270	5,538
Southern California Gas Company \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - San Diego Gas and Electric Company - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Jointly Owned Nuclear Power Plant
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20%
Anticipated term of dismantlement work	10 years
Percent of dismantlement work expense (as a percent)	20%
ARO related to decommissioning costs	$ 523
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 81

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Cost	$ 673		$ 673		$ 689
Gross unrealized gains	224		224		196
Gross unrealized losses	(34)		(34)		(44)
Estimated fair value	863		863		841
Proceeds from sales	138	$ 155	294	$ 397
Gross realized gains	6	3	8	14
Gross realized losses	(3)	$ (7)	(6)	$ (11)
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	551		551		571
Gross unrealized gains	2		2		2
Gross unrealized losses	(30)		(30)		(36)
Estimated fair value	523		523		537
U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	40		40		40
Gross unrealized gains	1		1		1
Gross unrealized losses	(2)		(2)		(1)
Estimated fair value	39		39		40
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	277		277		283
Gross unrealized gains	1		1		1
Gross unrealized losses	(12)		(12)		(14)
Estimated fair value	266		266		270
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	234		234		248
Gross unrealized gains	0		0		0
Gross unrealized losses	(16)		(16)		(21)
Estimated fair value	218		218		227
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	104		104		111
Gross unrealized gains	222		222		194
Gross unrealized losses	(4)		(4)		(8)
Estimated fair value	322		322		297
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	24		24		11
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	24		24		11
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(6)		(6)		(4)
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (6)		$ (6)		$ (4)

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended		12 Months Ended	22 Months Ended
	Jul. 31, 2023 plaintiff	Sep. 30, 2021 USD ($) plaintiff lawsuit	Jun. 30, 2023 USD ($) lawsuit	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) lawsuit	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Jul. 31, 2023 plaintiff	Nov. 30, 2021 Bcf	Jan. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 222		$ 222
Natural gas inventory level (in bcf) \| Bcf									41.16
Aliso Canyon litigation and regulatory matters			0	$ 45	0	$ 137
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings			126		126
Southern California Gas Company
Loss Contingencies [Line Items]
Liability for legal proceedings			142		142
Aliso Canyon litigation and regulatory matters			0	45	0	137
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings			126		126
Number of lawsuits \| lawsuit		390
Number of plaintiffs \| plaintiff		36,000
Net book value of Aliso Canyon facility			976		976
Reserve for Aliso Canyon costs			$ 126		$ 126
Aliso Canyon litigation and regulatory matters, net of tax				$ 32		$ 98
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff	243
Southern California Gas Company \| Shareholder Derivative Complaint
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit			4		4					3
Southern California Gas Company \| Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs		$ 1,800
Percentage of plaintiffs agreeing to participate and submit releases (in percent)							99%
Payment of liquidating companies' costs							$ 1,790
Southern California Gas Company \| The Developer Plaintiffs \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff								388
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 6		$ 6
Deferred Credits and Other \| Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Reserve for Aliso Canyon costs			$ 2		$ 2

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	1 Months Ended		6 Months Ended
	Oct. 31, 2020 GBP (£)	Mar. 31, 2020 GBP (£)	Jun. 30, 2023 USD ($)	Jul. 31, 2023 lawsuit claim
Plaintiffs \| HMRC VAT Claim
Loss Contingencies [Line Items]
Damages awarded		£ 45	$ 57
Cost and interest assessed	£ 21		$ 27
Energy Future Holdings Corp. \| Subsequent Event
Loss Contingencies [Line Items]
Lawsuits pending \| lawsuit				2
Number of proof of claims \| claim				28,000

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) agreement
San Diego Gas and Electric Company
Lessee, Lease, Description [Line Items]
Right-of-use asset and lease liability	$ 101
Undiscounted lease payments due remainder of the year	9
Undiscounted lease payments due year one	13
Undiscounted lease payments due year two	13
Undiscounted lease payments due year three	13
Undiscounted lease payments due year four	13
Undiscounted lease payments due thereafter	$ 66
Number of energy storage agreements \| agreement	4
Lease not yet commenced, remainder of year	$ 1
Lease not yet commenced, year one	32
Lease not yet commenced, year two	41
Lease not yet commenced, year three	41
Lease not yet commenced, year four	40
Lease not yet commenced, thereafter	377
Southern California Gas Company
Lessee, Lease, Description [Line Items]
Finance lease not yet commenced, year one	1
Finance lease not yet commenced, year two	1
Finance lease not yet commenced, year three	1
Finance lease not yet commenced, year four	1
Finance lease not yet commenced, year thereafter	$ 6

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Interest income	$ 1	$ 2	$ 3	$ 4
Total revenues from sales-type leases	1	2	3	4
Fixed lease payments	76	70	156	140
Variable lease payments	14	3	16	4
Total revenues from operating leases	90	73	172	144
Depreciation expense	$ 15	$ 14	$ 30	$ 27

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS & ENVIRONMENTAL ISSUES (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Loss Contingencies [Line Items]
Potential monetary sanctions threshold	$ 1
Potential monetary sanctions threshold (as a percent)	1%
Environmental cost, potential monetary sanctions threshold, actual amount	$ 48
Sempra Infrastructure \| Natural Gas Storage and Transportation Contracts
Loss Contingencies [Line Items]
Change since 2022	863
Change in 2023	(27)
Change in 2024	23
Change in 2025	33
Change in 2026	33
Change in 2027	30
Change thereafter	771
Sempra Infrastructure \| Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Change in 2023	(841)
Change in 2024	(87)
Change in 2025	(65)
Change in 2026	(87)
Change in 2027	(98)
Change thereafter	(208)
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	17
Southern California Gas Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	$ 13

SEGMENT INFORMATION - NARRATIVE

SEGMENT INFORMATION - NARRATIVE (Details)	6 Months Ended
SEGMENT INFORMATION - NARRATIVE (Details)	Jun. 30, 2023 segment
Segment Reporting Information [Line Items]
Number of reportable segments	4
Oncor Electric Delivery Company LLC Additional Acquisition \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	80.25%
Sharyland Holdings, LP \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	50%

SEGMENT INFORMATION - SCHEDULE

SEGMENT INFORMATION - SCHEDULE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 3,335	$ 3,547	$ 9,895	$ 7,367
DEPRECIATION AND AMORTIZATION	549	501	1,088	994
INTEREST INCOME	17	15	41	40
INTEREST EXPENSE	317	271	683	514
INCOME TAX EXPENSE (BENEFIT)	175	80	551	414
Equity earnings, before income tax:	153	159	285	302
Equity earnings, net of income tax:	235	216	322	399
Equity earnings	388	375	607	701
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	603	559	1,572	1,171
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			4,282	2,361
ASSETS	82,727		82,727		$ 78,574	[1]
EQUITY METHOD INVESTMENTS	16,015		16,015		15,677
Operating Segments \| SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,262	1,399	2,915	2,844
DEPRECIATION AND AMORTIZATION	268	244	530	483
INTEREST INCOME	4	1	5	1
INTEREST EXPENSE	123	114	241	220
INCOME TAX EXPENSE (BENEFIT)	4	42	11	106
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	184	176	442	410
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			1,239	1,090
ASSETS	27,786		27,786		26,422
Operating Segments \| SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,467	1,501	5,261	3,494
DEPRECIATION AND AMORTIZATION	208	188	414	375
INTEREST INCOME	1	1	5	1
INTEREST EXPENSE	71	45	140	85
INCOME TAX EXPENSE (BENEFIT)	(21)	19	73	103
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	155	87	515	421
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			961	931
ASSETS	22,591		22,591		22,346
Operating Segments \| Sempra Texas Utilities
Segment Reporting Information, Profit (Loss) [Abstract]
Equity earnings, before income tax:	2	3	3	5
Equity earnings, net of income tax:	160	184	243	346
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	160	186	243	348
Segment Reporting Information, Additional Information [Abstract]
ASSETS	13,988		13,988		13,781
EQUITY METHOD INVESTMENTS	13,979		13,979		13,772
Operating Segments \| Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	660	689	1,856	1,113
DEPRECIATION AND AMORTIZATION	70	67	139	132
INTEREST INCOME	6	9	21	30
INTEREST EXPENSE	25	32	120	59
INCOME TAX EXPENSE (BENEFIT)	201	70	531	161
Equity earnings, before income tax:	151	156	282	297
Equity earnings, net of income tax:	75	32	79	53
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	208	183	523	278
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			2,078	336
ASSETS	17,610		17,610		15,760
EQUITY METHOD INVESTMENTS	2,036		2,036		1,905
Adjustments and eliminations
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(2)	(2)	(1)	0
All other
Segment Reporting Information, Profit (Loss) [Abstract]
DEPRECIATION AND AMORTIZATION	3	2	5	4
INTEREST INCOME	6	4	10	8
INTEREST EXPENSE	99	81	183	151
INCOME TAX EXPENSE (BENEFIT)	(9)	(51)	(64)	44
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(104)	(73)	(151)	(286)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			4	4
ASSETS	1,773		1,773		1,376
Intersegment revenues and eliminations
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(52)	(40)	(136)	(84)
INTEREST EXPENSE	(1)	(1)	(1)	(1)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,021)		(1,021)		$ (1,111)
Intersegment revenues and eliminations \| SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(5)	(3)	(9)	(7)
Intersegment revenues and eliminations \| SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(28)	(23)	(62)	(49)
Intersegment revenues and eliminations \| Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ (19)	$ (14)	$ (65)	$ (28)

[1]Derived from audited financial statements.

SUBSEQUENT EVENT - Narrative (D

SUBSEQUENT EVENT - Narrative (Details)	Aug. 02, 2023 shares	Jun. 30, 2023 shares	May 12, 2023 shares	May 11, 2023 shares	Dec. 31, 2022 shares
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Common stock, shares authorized (in shares)		1,125,000,000	1,125,000,000	750,000,000	1,125,000,000
Subsequent Event
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Stock split, conversion ratio	2
Stock dividend (in percent)	100%
Common stock, shares authorized (in shares)	1,125,000,000

SUBSEQUENT EVENT - Pro Forma St

SUBSEQUENT EVENT - Pro Forma Stock Split (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Numerator:
Earnings attributable to common shares, basic	$ 603	$ 559	$ 1,572	$ 1,171
Earnings attributable to common shares, diluted	$ 603	$ 559	$ 1,572	$ 1,171
Denominator:
Weighted-average common shares outstanding for basic EPS (in shares)	630,014	629,691	629,926	631,190
Dilutive effect of stock options and RSUs (in shares)	2,107	2,044	2,259	2,104
Weighted-average common shares outstanding for diluted EPS (in shares)	632,121	631,735	632,185	633,294
EPS:
Earnings per share, basic (dollars per share)	$ 0.96	$ 0.89	$ 2.50	$ 1.86
Earnings per share, diluted (in dollars per share)	$ 0.95	$ 0.89	$ 2.49	$ 1.85
Vested RSUs included in basic WASO (in shares)	355	399	358	403
Pro Forma
EPS:
Vested RSUs included in basic WASO (in shares)	710	798	716	806