Southern California Gas Company PFD SER A 6% (SOCGP) 10-Q 6 Nov 24 2024 Q3 Quarterly report Financial data

COVER

COVER - shares	9 Months Ended
	Sep. 30, 2024	Nov. 01, 2024
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2024
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		633,399,264
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
SDG&E
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0000086521
SoCalGas
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth 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		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
REVENUES
Natural gas	$ 1,195	$ 1,488	$ 4,798	$ 7,560
Electric	1,069	1,250	3,269	3,331
Energy-related businesses	512	596	1,360	2,338
Total revenues	2,776	3,334	9,427	13,229
Operating expenses:
Operation and maintenance	(1,326)	(1,383)	(3,871)	(3,958)
Depreciation and amortization	(614)	(563)	(1,811)	(1,651)
Franchise fees and other taxes	(175)	(169)	(515)	(509)
Other income, net	65	3	194	75
Interest income	17	19	47	60
Interest expense	(328)	(312)	(944)	(995)
Income before income taxes and equity earnings	200	323	1,213	2,175
Income tax benefit (expense)	105	52	63	(499)
Equity earnings	454	479	1,235	1,086
Net income	759	854	2,511	2,762
Earnings attributable to noncontrolling interests	(110)	(122)	(325)	(435)
Preferred dividends	(11)	(11)	(33)	(33)
Preferred dividends of subsidiary	0	0	(1)	(1)
Earnings attributable to common shares	$ 638	$ 721	$ 2,152	$ 2,293
Basic EPS:
Earnings (in dollars per share)	$ 1.01	$ 1.14	$ 3.40	$ 3.64
Weighted-average common shares outstanding (in shares)	633,752	630,036	633,342	629,963
Diluted EPS:
Earnings (in dollars per share)	$ 1	$ 1.14	$ 3.38	$ 3.63
Weighted-average common shares outstanding (in shares)	638,061	632,324	636,566	632,231
Natural gas
Operating expenses:
Operating expenses	$ (99)	$ (260)	$ (790)	$ (3,254)
Electric fuel and purchased power
Operating expenses:
Operating expenses	18	(183)	(227)	(385)
Energy-related businesses
Operating expenses:
Operating expenses	$ (134)	$ (163)	$ (297)	$ (437)

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Statement of Comprehensive Income [Abstract]
Net income, pretax amount, attributable to parent	$ 544	$ 680	$ 2,123	$ 2,826
Income tax benefit (expense)	105	52	63	(499)
Net income, after tax amounts, attributable to parent	649	732	2,186	2,327
Net income, Non-controlling interest (after tax)	110	122	325	435
Net income	759	854	2,511	2,762
Foreign currency translation adjustments
Foreign currency translation adjustments, pretax amount, attributable to parent	(12)	(5)	(25)	16
Foreign currency translation adjustments, income tax (expense) benefit, attributable to parent	0	0	0	0
Foreign currency translation adjustments, net of tax amount, attributable to parent	(12)	(5)	(25)	16
Foreign currency translation adjustments, net of tax amount, attributable to noncontrolling interests	(5)	(2)	(11)	6
Total foreign currency translation adjustments	(17)	(7)	(36)	22
Financial instruments
Financial instruments, pretax amount, attributable to parent	(74)	150	(26)	158
Financial instruments, income tax (expense) benefit, attributable to parent	20	(39)	4	(43)
Financial instruments, net of tax amount, attributable to parent	(54)	111	(22)	115
Financial instruments, after tax amount, attributable to noncontrolling interests	(171)	204	(2)	206
Pretax gain (loss) reclassified from AOCI into earnings	(225)	315	(24)	321
Pension and other postretirement benefits
Pension and other postretirement benefits, pretax amount, attributable to parent	3	2	16	(8)
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(1)	(1)	(4)	(2)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	1	12	(10)
Pension and other postretirement benefits, net of tax amount, attributable to noncontrolling interests	0	0	0	0
Total pension and other postretirement benefits	2	1	12	(10)
Total other comprehensive income (loss), pretax amount, attributable to parent	(83)	147	(35)	166
Total other comprehensive income (loss), income tax (expense) benefit, attributable to parent	19	(40)	0	(45)
Total other comprehensive income (loss), net of tax amount, attributable to parent	(64)	107	(35)	121
Total other comprehensive income (loss), net of tax amount, attributable to noncontrolling interests	(176)	202	(13)	212
Total other comprehensive loss	(240)	309	(48)	333
Comprehensive income, pretax amount, attributable to parent	461	827	2,088	2,992
Comprehensive income, income tax (expense) benefit, attributable to parent	124	12	63	(544)
Comprehensive income, net of tax amount, attributable to parent	585	839	2,151	2,448
Comprehensive income, net of tax amount, attributable to noncontrolling interests	(66)	324	312	647
Total comprehensive income	$ 519	$ 1,163	2,463	3,095
Preferred dividends of subsidiary, pretax amount, attributable to parent			(1)	(1)
Preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent			0	0
Preferred dividends of subsidiary, net of tax amount, attributable to parent			(1)	(1)
Preferred dividends of subsidiary, net of tax amount, attributable to noncontrolling interests			0	0
Total preferred dividends of subsidiary			(1)	(1)
Comprehensive income, pretax amount, attributable to parent			2,087	2,991
Comprehensive income, income tax (expense) benefit, attributable to parent			63	(544)
Comprehensive income			2,150	2,447
Comprehensive income, net of tax amount, attributable to noncontrolling interest			312	647
Total comprehensive income			$ 2,462	$ 3,094

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 560	$ 236	[1]
Restricted cash	22	49	[1]
Accounts receivable – trade, net	1,716	2,151	[1]
Accounts receivable – other, net	422	561	[1]
Due from unconsolidated affiliates	14	31	[1]
Income taxes receivable	152	94	[1]
Inventories	519	482	[1]
Prepaid expenses	314	273	[1]
Regulatory assets	59	226	[1]
Fixed-price contracts and other derivatives	111	122	[1]
Greenhouse gas allowances	1,169	1,189	[1]
Other current assets	41	56	[1]
Total current assets	5,099	5,470	[1]
Other assets:
Restricted cash	108	104	[1]
Regulatory assets	4,325	3,771	[1]
Greenhouse gas allowances	971	301	[1]
Nuclear decommissioning trusts	906	872	[1]
Dedicated assets in support of certain benefit plans	585	549	[1]
Deferred income taxes	144	129	[1]
Right-of-use assets – operating leases	888	723	[1]
Investment in Oncor Holdings	15,160	14,266	[1]
Other investments	2,412	2,244	[1]
Goodwill	1,602	1,602	[1]
Other intangible assets	299	318	[1]
Wildfire fund	268	269	[1]
Other long-term assets	1,706	1,603	[1]
Total other assets	29,374	26,751	[1]
Property, plant and equipment:
Property, plant and equipment	77,896	72,495	[1]
Less accumulated depreciation and amortization	(18,621)	(17,535)	[1]
Property, plant and equipment, net	59,275	54,960	[1]
Total assets	93,748	87,181	[1]
Current liabilities:
Short-term debt	2,187	2,342	[1]
Accounts payable – trade	1,966	2,211	[1]
Accounts payable – other	227	224	[1]
Dividends and interest payable	816	691	[1]
Accrued compensation and benefits	541	526	[1]
Regulatory liabilities	523	553	[1]
Current portion of long-term debt and finance leases	1,212	975	[1]
Greenhouse gas obligations	1,169	1,189	[1]
Total current liabilities	9,843	10,090	[1]
Long-term debt and finance leases	30,964	27,759	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	347	307	[1]
Regulatory liabilities	4,118	3,739	[1]
Greenhouse gas obligations	495	0	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	377	407	[1]
Deferred income taxes	5,404	5,254	[1]
Asset retirement obligations	3,710	3,642	[1]
Deferred credits and other	2,610	2,329	[1]
Total deferred credits and other liabilities	17,061	15,678	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,292	12,204	[1]
Retained earnings	16,707	15,732	[1]
Accumulated other comprehensive income (loss)	(185)	(150)	[1]
Total shareholders’ equity	29,703	28,675	[1]
Preferred stock of subsidiary	20	20	[1]
Other noncontrolling interests	6,157	4,959	[1]
Total equity	35,880	33,654	[1]
Total liabilities and equity	93,748	87,181	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	14	31
Current liabilities:
Other current liabilities	0	5	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	347	307
Nonrelated Party
Current liabilities:
Other current liabilities	1,202	1,374	[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	Sep. 30, 2024	Dec. 31, 2023
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)	633,214,870	631,431,732
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	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,511	$ 2,762
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,811	1,651
Deferred income taxes and investment tax credits	(223)	234
Equity earnings	(1,235)	(1,086)
Share-based compensation expense	63	53
Fixed-price contracts and other derivatives	11	(580)
Bad debt expense	149	368
Other	7	6
Net change in working capital components	55	1,610
Distributions from investments	654	668
Changes in other noncurrent assets and liabilities, net	(261)	(557)
Net cash provided by operating activities	3,542	5,129
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,765)	(6,074)
Expenditures for investments	(588)	(281)
Purchases of nuclear decommissioning and other trust assets	(658)	(462)
Proceeds from sales of nuclear decommissioning and other trust assets	704	503
Other	11	10
Net cash used in investing activities	(6,296)	(6,304)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,121)	(1,109)
Preferred dividends paid	(22)	(22)
Issuances of common stock	26	0
Repurchases of common stock	(41)	(32)
Issuances of debt (maturities greater than 90 days)	6,437	6,911
Payments on debt (maturities greater than 90 days) and finance leases	(2,216)	(6,018)
(Decrease) increase in short-term debt, net	(929)	629
Advances from unconsolidated affiliates	85	31
Proceeds from sales of noncontrolling interests, net	0	1,238
Distributions to noncontrolling interests	(235)	(289)
Contributions from noncontrolling interests	1,121	1,036
Settlement of cross-currency swaps	0	(99)
Other	(39)	(78)
Net cash provided by financing activities	3,066	2,198
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(11)	6
Increase in cash, cash equivalents and restricted cash	301	1,029
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, September 30	690	1,491
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	814	836
Income tax payments, net of refunds	272	162
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued interest receivable added to note receivable	13	12
Repayments of advances from unconsolidated affiliate in lieu of distributions	62	36
Accrued capital expenditures	1,059	1,200
Increase in finance lease obligations for investment in PP&E	27	47
Decrease in ARO for investment in PP&E	(9)	(15)
Common dividends issued in stock	40	0
Contributions from NCI	0	200
Sale of NCI post-closing adjustment payable	0	11
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	22	22
Common stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	$ 392	$ 374

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series C Preferred Stock	Sempra shareholders' equity	Sempra shareholders' equity Series C Preferred Stock	Preferred stock	Common stock	Retained earnings	Retained earnings Series C Preferred Stock	Accumulated other comprehensive income (loss)	Non- controlling interests
Beginning Balance at Dec. 31, 2022	$ 29,256			$ 27,115		$ 889	$ 12,160	$ 14,201		$ (135)	$ 2,141
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,762			2,327				2,327			435
Other comprehensive income (loss)	333			121						121	212
Share-based compensation expense	53			53			53
Dividends declared:
Preferred dividends			$ (33)		$ (33)				$ (33)
Common stock dividends	(1,123)			(1,123)				(1,123)
Preferred dividends of subsidiary	(1)			(1)				(1)
Repurchases of common stock	(32)			(32)			(32)
Noncontrolling interest activities:
Contributions	1,091			(145)			(145)				1,236
Distributions	(289)										(289)
Sales	1,241			(44)			2			(46)	1,285
Ending balance at Sep. 30, 2023	33,258			28,238		889	12,038	15,371		(60)	5,020
Beginning Balance at Jun. 30, 2023	31,014			27,836		889	12,044	15,024		(121)	3,178
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	854			732				732			122
Other comprehensive income (loss)	309			107						107	202
Share-based compensation expense	22			22			22
Dividends declared:
Preferred dividends			(11)		(11)				(11)
Common stock dividends	(374)			(374)				(374)
Repurchases of common stock	(1)			(1)			(1)
Noncontrolling interest activities:
Contributions	496			(11)			(11)				507
Distributions	(37)										(37)
Sales	986			(62)			(16)			(46)	1,048
Ending balance at Sep. 30, 2023	33,258			28,238		889	12,038	15,371		(60)	5,020
Beginning Balance at Dec. 31, 2023	33,654	[1]		28,675		889	12,204	15,732		(150)	4,979
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,511			2,186				2,186			325
Other comprehensive income (loss)	(48)			(35)						(35)	(13)
Share-based compensation expense	63			63			63
Dividends declared:
Preferred dividends			(33)		(33)				(33)
Common stock dividends	(1,177)			(1,177)				(1,177)
Preferred dividends of subsidiary	(1)			(1)				(1)
Issuances of common stock	66			66			66
Repurchases of common stock	(41)			(41)			(41)
Noncontrolling interest activities:
Contributions	1,121										1,121
Distributions	(235)										(235)
Ending balance at Sep. 30, 2024	35,880			29,703		889	12,292	16,707		(185)	6,177
Beginning Balance at Jun. 30, 2024	35,419			29,479		889	12,250	16,461		(121)	5,940
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	759			649				649			110
Other comprehensive income (loss)	(240)			(64)						(64)	(176)
Share-based compensation expense	22			22			22
Dividends declared:
Preferred dividends			$ (11)		$ (11)				$ (11)
Common stock dividends	(392)			(392)				(392)
Issuances of common stock	21			21			21
Repurchases of common stock	(1)			(1)			(1)
Noncontrolling interest activities:
Contributions	335										335
Distributions	(32)										(32)
Ending balance at Sep. 30, 2024	$ 35,880			$ 29,703		$ 889	$ 12,292	$ 16,707		$ (185)	$ 6,177
[1] Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Dividends declared per share of common stock (in dollars per share)	$ 0.62	$ 0.60	$ 1.86	$ 1.79
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19	$ 36.57	$ 36.57

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
REVENUES
Electric	$ 1,069	$ 1,250	$ 3,269	$ 3,331
Natural gas	1,195	1,488	4,798	7,560
Operating expenses:
Other income, net	65	3	194	75
Interest income	17	19	47	60
Interest expense	(328)	(312)	(944)	(995)
Income before income taxes and equity earnings	200	323	1,213	2,175
Income tax benefit (expense)	105	52	63	(499)
Net income	759	854	2,511	2,762
Earnings attributable to common shares	638	721	2,152	2,293
SDG&E
REVENUES
Electric	1,073	1,254	3,282	3,343
Natural gas	170	188	695	1,014
Operating revenues	1,243	1,442	3,977	4,357
Operating expenses:
Cost of electric fuel and purchased power	(5)
Cost of electric fuel and purchased power		200	277	442
Cost of natural gas	38	45	177	462
Operation and maintenance	420	463	1,254	1,364
Depreciation and amortization	308	280	910	810
Franchise fees and other taxes	106	101	301	287
Total operating expenses	867	1,089	2,919	3,365
Operating income	376	353	1,058	992
Other income, net	30	25	86	75
Interest income	1	7	5	12
Interest expense	(131)	(126)	(390)	(367)
Income before income taxes and equity earnings	276	259	759	712
Income tax benefit (expense)	(15)	15	(89)	4
Net income	261	274	670	716
Earnings attributable to common shares	$ 261	$ 274	$ 670	$ 716

CONDENSED STATEMENTS OF COMPREH

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Net income, pretax amount, attributable to parent	$ 544	$ 680	$ 2,123	$ 2,826
Income tax benefit (expense)	105	52	63	(499)
Net income, after tax amounts, attributable to parent	649	732	2,186	2,327
Other comprehensive income (loss):
Pension and other postretirement benefits, pretax amount, attributable to parent	3	2	16	(8)
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(1)	(1)	(4)	(2)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	1	12	(10)
Total other comprehensive income (loss), pretax amount, attributable to parent	(83)	147	(35)	166
Total other comprehensive income (loss), income tax (expense) benefit, attributable to parent	19	(40)	0	(45)
Total other comprehensive income (loss), net of tax amount, attributable to parent	(64)	107	(35)	121
Comprehensive income, pretax amount, attributable to parent			2,087	2,991
Comprehensive income, income tax (expense) benefit, attributable to parent			63	(544)
Comprehensive income			2,150	2,447
SDG&E
Net income, pretax amount, attributable to parent	276	259	759	712
Income tax benefit (expense)	(15)	15	(89)	4
Net income, after tax amounts, attributable to parent	$ 261	274	$ 670	716
Other comprehensive income (loss):
Comprehensive income, pretax amount, attributable to parent		259		712
Comprehensive income, income tax (expense) benefit, attributable to parent		15		4
Comprehensive income		$ 274		$ 716

CONDENSED BALANCE SHEETS - SDG&

CONDENSED BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 560	$ 236	[1]
Accounts receivable – trade, net	1,716	2,151	[1]
Accounts receivable – other, net	422	561	[1]
Due from unconsolidated affiliates	14	31	[1]
Income taxes receivable	152	94	[1]
Inventories	519	482	[1]
Prepaid expenses	314	273	[1]
Regulatory assets	59	226	[1]
Greenhouse gas allowances	1,169	1,189	[1]
Other current assets	41	56	[1]
Total current assets	5,099	5,470	[1]
Other assets:
Regulatory assets	4,325	3,771	[1]
Greenhouse gas allowances	971	301	[1]
Nuclear decommissioning trusts	906	872	[1]
Right-of-use assets – operating leases	888	723	[1]
Wildfire fund	268	269	[1]
Other long-term assets	1,706	1,603	[1]
Total other assets	29,374	26,751	[1]
Property, plant and equipment:
Property, plant and equipment	77,896	72,495	[1]
Less accumulated depreciation and amortization	(18,621)	(17,535)	[1]
Property, plant and equipment, net	59,275	54,960	[1]
Total assets	93,748	87,181	[1]
Current liabilities:
Short-term debt	2,187	2,342	[1]
Accrued compensation and benefits	541	526	[1]
Regulatory liabilities	523	553	[1]
Current portion of long-term debt and finance leases	1,212	975	[1]
Greenhouse gas obligations	1,169	1,189	[1]
Total current liabilities	9,843	10,090	[1]
Long-term debt and finance leases	30,964	27,759	[1]
Deferred credits and other liabilities:
Regulatory liabilities	4,118	3,739	[1]
Greenhouse gas obligations	495	0	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	377	407	[1]
Deferred income taxes	5,404	5,254	[1]
Asset retirement obligations	3,710	3,642	[1]
Deferred credits and other	2,610	2,329	[1]
Total deferred credits and other liabilities	17,061	15,678	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,292	12,204	[1]
Retained earnings	16,707	15,732	[1]
Accumulated other comprehensive income (loss)	(185)	(150)	[1]
Total shareholders’ equity	29,703	28,675	[1]
Total liabilities and equity	93,748	87,181	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	14	31
Current liabilities:
Other current liabilities	0	5	[1]
Nonrelated Party
Current liabilities:
Other current liabilities	1,202	1,374	[1]
SDG&E
Current assets:
Cash and cash equivalents	15	50	[1]
Accounts receivable – trade, net	867	870	[1]
Accounts receivable – other, net	108	141	[1]
Due from unconsolidated affiliates	8	0	[1]
Income taxes receivable	240	236	[1]
Inventories	182	153	[1]
Prepaid expenses	171	165	[1]
Regulatory assets	15	19	[1]
Greenhouse gas allowances	158	158	[1]
Other current assets	30	31	[1]
Total current assets	1,794	1,823	[1]
Other assets:
Regulatory assets	2,164	1,968	[1]
Greenhouse gas allowances	298	202	[1]
Nuclear decommissioning trusts	906	872	[1]
Right-of-use assets – operating leases	542	368	[1]
Wildfire fund	268	269	[1]
Other long-term assets	165	134	[1]
Total other assets	4,343	3,813	[1]
Property, plant and equipment:
Property, plant and equipment	32,480	30,918	[1]
Less accumulated depreciation and amortization	(7,852)	(7,369)	[1]
Property, plant and equipment, net	24,628	23,549	[1]
Total assets	30,765	29,185	[1]
Current liabilities:
Short-term debt	384	0	[1]
Accounts payable	823	808	[1]
Interest payable	117	81	[1]
Accrued compensation and benefits	162	145	[1]
Accrued franchise fees	53	112	[1]
Regulatory liabilities	264	447	[1]
Current portion of long-term debt and finance leases	41	441	[1]
Greenhouse gas obligations	158	158	[1]
Asset retirement obligations	110	116	[1]
Total current liabilities	2,434	2,597	[1]
Long-term debt and finance leases	10,021	9,453	[1]
Deferred credits and other liabilities:
Regulatory liabilities	2,771	2,534	[1]
Greenhouse gas obligations	65	0	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	77	79	[1]
Deferred income taxes	3,080	2,873	[1]
Asset retirement obligations	771	778	[1]
Deferred credits and other	1,199	969	[1]
Total deferred credits and other liabilities	7,963	7,233	[1]
Commitments and contingencies			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,660	1,660	[1]
Retained earnings	8,695	8,250	[1]
Accumulated other comprehensive income (loss)	(8)	(8)	[1]
Total shareholders’ equity	10,347	9,902	[1]
Total liabilities and equity	30,765	29,185	[1]
SDG&E | Related Party
Current assets:
Due from unconsolidated affiliates	8	0
Current liabilities:
Other current liabilities	48	73	[1]
SDG&E | Nonrelated Party
Current liabilities:
Other current liabilities	$ 274	$ 216	[1]
[1] Derived from audited financial statements.

CONDENSED BALANCE SHEETS - SD_2

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Sep. 30, 2024	Dec. 31, 2023
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)	633,214,870	631,431,732
SDG&E
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)	116,583,358	116,583,358

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,511	$ 2,762
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,811	1,651
Deferred income taxes and investment tax credits	(223)	234
Bad debt expense	149	368
Other	7	6
Net change in working capital components	55	1,610
Changes in other noncurrent assets and liabilities, net	(261)	(557)
Net cash provided by operating activities	3,542	5,129
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,765)	(6,074)
Purchases of nuclear decommissioning trust assets	(658)	(462)
Proceeds from sales of nuclear decommissioning trust assets	704	503
Other	11	10
Net cash used in investing activities	(6,296)	(6,304)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,121)	(1,109)
Issuances of debt (maturities greater than 90 days)	6,437	6,911
Payments on debt (maturities greater than 90 days) and finance leases	(2,216)	(6,018)
(Decrease) increase in short-term debt, net	(929)	629
Net cash provided by financing activities	3,066	2,198
Increase in cash, cash equivalents and restricted cash	301	1,029
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, September 30	690	1,491
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	814	836
Income tax payments, net of refunds	272	162
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,059	1,200
Increase in finance lease obligations for investment in PP&E	27	47
Increase in ARO for investment in PP&E	(9)	(15)
SDG&E
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	670	716
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	910	810
Deferred income taxes and investment tax credits	94	(56)
Bad debt expense	46	94
Other	(19)	(30)
Net change in working capital components	(204)	269
Changes in other noncurrent assets and liabilities, net	(54)	(319)
Net cash provided by operating activities	1,443	1,484
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,838)	(1,893)
Purchases of nuclear decommissioning trust assets	(605)	(391)
Proceeds from sales of nuclear decommissioning trust assets	639	437
Other	11	9
Net cash used in investing activities	(1,793)	(1,838)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(225)	(100)
Issuances of debt (maturities greater than 90 days)	594	1,389
Payments on debt (maturities greater than 90 days) and finance leases	(432)	(479)
(Decrease) increase in short-term debt, net	384	(205)
Debt issuance costs	(6)	(12)
Net cash provided by financing activities	315	593
Increase in cash, cash equivalents and restricted cash	(35)	239
Cash, cash equivalents and restricted cash, January 1	50	7
Cash, cash equivalents and restricted cash, September 30	15	246
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	348	315
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	214	237
Increase in finance lease obligations for investment in PP&E	8	7
Increase in ARO for investment in PP&E	$ 0	$ 13

CONDENSED STATEMENTS OF CHANGES

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E - USD ($) $ in Millions	Total		Retained earnings	Accumulated other comprehensive income (loss)	SDG&E		SDG&E Common stock	SDG&E Retained earnings	SDG&E Accumulated other comprehensive income (loss)
Beginning balance at Dec. 31, 2022				$ (135)	$ 9,067		$ 1,660	$ 7,414	$ (7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 2,762		$ 2,327		716			716
Other comprehensive income (loss)	333			121
Common stock dividends	(1,123)		(1,123)		(100)			(100)
Ending balance at Sep. 30, 2023				(60)	9,683		1,660	8,030	(7)
Beginning balance at Jun. 30, 2023				(121)	9,509		1,660	7,856	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	854		732		274			274
Other comprehensive income (loss)	309			107
Common stock dividends	(374)		(374)		(100)			(100)
Ending balance at Sep. 30, 2023				(60)	9,683		1,660	8,030	(7)
Beginning balance at Dec. 31, 2023	28,675	[1]		(150)	9,902	[1]	1,660	8,250	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,511		2,186		670			670
Other comprehensive income (loss)	(48)			(35)
Common stock dividends	(1,177)		(1,177)		(225)			(225)
Ending balance at Sep. 30, 2024	29,703			(185)	10,347		1,660	8,695	(8)
Beginning balance at Jun. 30, 2024				(121)	10,311		1,660	8,659	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	759		649		261			261
Other comprehensive income (loss)	(240)			(64)
Common stock dividends	(392)		$ (392)		(225)			(225)
Ending balance at Sep. 30, 2024	$ 29,703			$ (185)	$ 10,347		$ 1,660	$ 8,695	$ (8)
[1] Derived from audited financial statements.

CONDENSED STATEMENTS OF CHANG_2

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Dividends declared per share of common stock (in dollars per share)	$ 0.62	$ 0.60	$ 1.86	$ 1.79
SDG&E
Dividends declared per share of common stock (in dollars per share)	$ 1.93	$ 0.86	$ 1.93	$ 0.86

CONDENSED STATEMENTS OF OPERA_2

CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Operating expenses:
Other income, net	$ 65	$ 3	$ 194	$ 75
Interest income	17	19	47	60
Interest expense	(328)	(312)	(944)	(995)
Income before income taxes and equity earnings	200	323	1,213	2,175
Income tax benefit (expense)	105	52	63	(499)
Net income	759	854	2,511	2,762
Preferred dividends	(11)	(11)	(33)	(33)
Earnings attributable to common shares	638	721	2,152	2,293
SoCalGas
REVENUES
Operating revenues	1,054	1,313	4,168	6,574
Operating expenses:
Cost of natural gas	82	224	661	2,855
Operation and maintenance	678	733	1,998	2,073
Depreciation and amortization	228	211	675	625
Franchise fees and other taxes	66	64	200	209
Total operating expenses	1,054	1,232	3,534	5,762
Operating income	0	81	634	812
Other income, net	13	(2)	73	(9)
Interest income	3	2	7	7
Interest expense	(82)	(70)	(237)	(210)
Income before income taxes and equity earnings	(66)	11	477	600
Income tax benefit (expense)	52	5	(1)	(68)
Net income	(14)	16	476	532
Preferred dividends	0	0	(1)	(1)
Earnings attributable to common shares	$ (14)	$ 16	$ 475	$ 531

CONDENSED STATEMENTS OF COMPR_2

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SCG - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Net income, pretax amount, attributable to parent	$ 544	$ 680	$ 2,123	$ 2,826
Income tax benefit (expense)	105	52	63	(499)
Net income, after tax amounts, attributable to parent	649	732	2,186	2,327
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent	(74)	150	(26)	158
Financial instruments, income tax (expense) benefit, attributable to parent	20	(39)	4	(43)
Financial instruments, net of tax amount, attributable to parent	(54)	111	(22)	115
Pension and other postretirement benefits, pretax amount, attributable to parent	3	2	16	(8)
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(1)	(1)	(4)	(2)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	1	12	(10)
Total other comprehensive income (loss), pretax amount, attributable to parent	(83)	147	(35)	166
Total other comprehensive income (loss), income tax (expense) benefit, attributable to parent	19	(40)	0	(45)
Total other comprehensive income (loss), net of tax amount, attributable to parent	(64)	107	(35)	121
Comprehensive income, pretax amount, attributable to parent			2,087	2,991
Comprehensive income, income tax (expense) benefit, attributable to parent			63	(544)
Comprehensive income			2,150	2,447
SoCalGas
Net income, pretax amount, attributable to parent	(66)	11	477	600
Income tax benefit (expense)	52	5	(1)	(68)
Net income, after tax amounts, attributable to parent	$ (14)	16	476	532
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent			1	1
Financial instruments, income tax (expense) benefit, attributable to parent			0	0
Financial instruments, net of tax amount, attributable to parent		0	1	1
Pension and other postretirement benefits, pretax amount, attributable to parent		1	1	2
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent		(1)	0	(1)
Pension and other postretirement benefits, net of tax amount, attributable to parent			1	1
Total other comprehensive income (loss), pretax amount, attributable to parent		1	2	3
Total other comprehensive income (loss), income tax (expense) benefit, attributable to parent		(1)	0	(1)
Total other comprehensive income (loss), net of tax amount, attributable to parent		0	2	2
Comprehensive income, pretax amount, attributable to parent		12	479	603
Comprehensive income, income tax (expense) benefit, attributable to parent		4	(1)	(69)
Comprehensive income		$ 16	$ 478	$ 534

CONDENSED BALANCE SHEETS - SoCa

CONDENSED BALANCE SHEETS - SoCalGas - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 560	$ 236	[1]
Accounts receivable – trade, net	1,716	2,151	[1]
Accounts receivable – other, net	422	561	[1]
Due from unconsolidated affiliates	14	31	[1]
Inventories	519	482	[1]
Regulatory assets	59	226	[1]
Greenhouse gas allowances	1,169	1,189	[1]
Other current assets	41	56	[1]
Total current assets	5,099	5,470	[1]
Other assets:
Regulatory assets	4,325	3,771	[1]
Greenhouse gas allowances	971	301	[1]
Right-of-use assets – operating leases	888	723	[1]
Other long-term assets	1,706	1,603	[1]
Total other assets	29,374	26,751	[1]
Property, plant and equipment:
Property, plant and equipment	77,896	72,495	[1]
Less accumulated depreciation and amortization	(18,621)	(17,535)	[1]
Property, plant and equipment, net	59,275	54,960	[1]
Total assets	93,748	87,181	[1]
Current liabilities:
Short-term debt	2,187	2,342	[1]
Accounts payable – trade	1,966	2,211	[1]
Accounts payable – other	227	224	[1]
Accrued compensation and benefits	541	526	[1]
Regulatory liabilities	523	553	[1]
Current portion of long-term debt and finance leases	1,212	975	[1]
Greenhouse gas obligations	1,169	1,189	[1]
Total current liabilities	9,843	10,090	[1]
Long-term debt and finance leases	30,964	27,759	[1]
Deferred credits and other liabilities:
Regulatory liabilities	4,118	3,739	[1]
Greenhouse gas obligations	495	0	[1]
Pension obligation, net of plan assets	377	407	[1]
Deferred income taxes	5,404	5,254	[1]
Asset retirement obligations	3,710	3,642	[1]
Deferred credits and other	2,610	2,329	[1]
Total deferred credits and other liabilities	17,061	15,678	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,292	12,204	[1]
Retained earnings	16,707	15,732	[1]
Accumulated other comprehensive income (loss)	(185)	(150)	[1]
Total shareholders’ equity	29,703	28,675	[1]
Total liabilities and equity	93,748	87,181	[1]
Related Party
Current assets:
Due from unconsolidated affiliates	14	31
Current liabilities:
Other current liabilities	0	5	[1]
Nonrelated Party
Current liabilities:
Other current liabilities	1,202	1,374	[1]
SoCalGas
Current assets:
Cash and cash equivalents	2	2	[1]
Accounts receivable – trade, net	557	985	[1]
Accounts receivable – other, net	75	102	[1]
Due from unconsolidated affiliates	2	22	[1]
Inventories	283	277	[1]
Regulatory assets	43	204	[1]
Greenhouse gas allowances	928	950	[1]
Other current assets	105	100	[1]
Total current assets	1,995	2,642	[1]
Other assets:
Regulatory assets	2,075	1,715	[1]
Greenhouse gas allowances	551	62	[1]
Right-of-use assets – operating leases	20	29	[1]
Other long-term assets	705	645	[1]
Total other assets	3,351	2,451	[1]
Property, plant and equipment:
Property, plant and equipment	28,369	27,025	[1]
Less accumulated depreciation and amortization	(8,253)	(7,852)	[1]
Property, plant and equipment, net	20,116	19,173	[1]
Total assets	25,462	24,266	[1]
Current liabilities:
Short-term debt	500	946	[1]
Accounts payable – trade	477	811	[1]
Accounts payable – other	179	184	[1]
Accrued compensation and benefits	247	213	[1]
Regulatory liabilities	257	103	[1]
Current portion of long-term debt and finance leases	373	523	[1]
Greenhouse gas obligations	928	950	[1]
Asset retirement obligations	72	73	[1]
Total current liabilities	3,557	4,407	[1]
Long-term debt and finance leases	7,027	6,288	[1]
Deferred credits and other liabilities:
Regulatory liabilities	1,346	1,202	[1]
Greenhouse gas obligations	396	0	[1]
Pension obligation, net of plan assets	199	231	[1]
Deferred income taxes	1,821	1,586	[1]
Asset retirement obligations	2,845	2,774	[1]
Deferred credits and other	384	368	[1]
Total deferred credits and other liabilities	6,991	6,161	[1]
Commitments and contingencies			[1]
Equity:
Preferred stock	22	22	[1]
Common stock	2,316	2,316	[1]
Retained earnings	5,570	5,095	[1]
Accumulated other comprehensive income (loss)	(21)	(23)	[1]
Total shareholders’ equity	7,887	7,410	[1]
Total liabilities and equity	25,462	24,266	[1]
SoCalGas | Related Party
Current assets:
Due from unconsolidated affiliates	2	22
Current liabilities:
Other current liabilities	43	38	[1]
SoCalGas | Nonrelated Party
Current liabilities:
Other current liabilities	$ 481	$ 566	[1]
[1] Derived from audited financial statements.

CONDENSED BALANCE SHEETS - So_2

CONDENSED BALANCE SHEETS - SoCalGas (Parentheticals) - shares	Sep. 30, 2024	Dec. 31, 2023
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)	633,214,870	631,431,732
SoCalGas
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	862,043	862,043
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,300,000	91,300,000

CONDENSED STATEMENTS OF CASH _2

CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,511	$ 2,762
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,811	1,651
Deferred income taxes and investment tax credits	(223)	234
Bad debt expense	149	368
Other	7	6
Net change in working capital components	55	1,610
Changes in other noncurrent assets and liabilities, net	(261)	(557)
Net cash provided by operating activities	3,542	5,129
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(5,765)	(6,074)
Net cash used in investing activities	(6,296)	(6,304)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(22)	(22)
Issuances of debt (maturities greater than 90 days)	6,437	6,911
Payments on debt (maturities greater than 90 days) and finance leases	(2,216)	(6,018)
(Decrease) increase in short-term debt, net	(929)	629
Net cash provided by financing activities	3,066	2,198
Increase in cash, cash equivalents and restricted cash	301	1,029
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, September 30	690	1,491
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	814	836
Income tax payments, net of refunds	272	162
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,059	1,200
Increase in finance lease obligations for investment in PP&E	27	47
Decrease in ARO for investment in PP&E	(9)	(15)
SoCalGas
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	476	532
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	675	625
Deferred income taxes and investment tax credits	4	79
Bad debt expense	70	272
Other	(21)	(9)
Net change in working capital components	321	(1)
Changes in other noncurrent assets and liabilities, net	(155)	(234)
Net cash provided by operating activities	1,370	1,264
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,491)	(1,451)
Net cash used in investing activities	(1,491)	(1,451)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)	(1)
Issuances of debt (maturities greater than 90 days)	1,594	997
Payments on debt (maturities greater than 90 days) and finance leases	(517)	(1,115)
(Decrease) increase in short-term debt, net	(946)	320
Debt issuance costs	(9)	(9)
Net cash provided by financing activities	121	192
Increase in cash, cash equivalents and restricted cash	0	5
Cash, cash equivalents and restricted cash, January 1	2	21
Cash, cash equivalents and restricted cash, September 30	2	26
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	189	183
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	265	253
Increase in finance lease obligations for investment in PP&E	19	40
Decrease in ARO for investment in PP&E	$ (9)	$ (28)

CONDENSED STATEMENTS OF CHANG_3

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas - USD ($) $ in Millions	Total		Retained earnings	Accumulated other comprehensive income (loss)	SoCalGas		SoCalGas Preferred stock	SoCalGas Common stock	SoCalGas Retained earnings	SoCalGas Accumulated other comprehensive income (loss)
Beginning balance at Dec. 31, 2022				$ (135)	$ 6,698		$ 22	$ 2,316	$ 4,384	$ (24)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 2,762		$ 2,327		532				532
Other comprehensive income (loss)	333			121	2					2
Dividends declared:
Preferred dividends					(1)				(1)
Ending balance at Sep. 30, 2023				(60)	7,231		22	2,316	4,915	(22)
Beginning balance at Jun. 30, 2023				(121)	7,215		22	2,316	4,899	(22)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	854		732		16				16
Other comprehensive income (loss)	309			107
Dividends declared:
Preferred dividends					0				0
Ending balance at Sep. 30, 2023				(60)	7,231		22	2,316	4,915	(22)
Beginning balance at Dec. 31, 2023	28,675	[1]		(150)	7,410	[1]	22	2,316	5,095	(23)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,511		2,186		476				476
Other comprehensive income (loss)	(48)			(35)	2					2
Dividends declared:
Preferred dividends					(1)				(1)
Ending balance at Sep. 30, 2024	29,703			(185)	7,887		22	2,316	5,570	(21)
Beginning balance at Jun. 30, 2024				(121)	7,901		22	2,316	5,584	(21)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	759		$ 649		(14)				(14)
Other comprehensive income (loss)	(240)			(64)
Dividends declared:
Preferred dividends					0				0
Ending balance at Sep. 30, 2024	$ 29,703			$ (185)	$ 7,887		$ 22	$ 2,316	$ 5,570	$ (21)
[1] Derived from audited financial statements.

CONDENSED STATEMENTS OF CHANG_4

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
SoCalGas
Dividends declared per share of preferred stock (in dollars per share)	$ 0.38	$ 0.38	$ 1.13	$ 1.13

GENERAL INFORMATION AND OTHER F

GENERAL INFORMATION AND OTHER FINANCIAL DATA	9 Months Ended
	Sep. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GENERAL INFORMATION AND OTHER FINANCIAL DATA	GENERAL INFORMATION AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities, which invest in, develop and operate energy infrastructure in North America, and provide electric and gas services to customers. Sempra has three separate reportable segments, which we describe in Note 12. In the fourth quarter of 2023, Sempra realigned its reportable segments to reflect changes in how the CODM oversees our three platforms: Sempra California, Sempra Texas Utilities and Sempra Infrastructure. Our former SDG&E and SoCalGas reportable segments were combined into one operating and reportable segment, Sempra California, which is consistent with how the CODM assesses performance due to the similarities of their operations, including geographic location and regulatory framework in California. Sempra’s historical segment disclosures have been restated to conform with the current presentation, so that all discussions reflect the revised segment information of its three reportable segments. 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. SDG&E is a regulated public utility that provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. SDG&E has one reportable segment. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra. SoCalGas is a regulated public natural gas distribution utility, serving customers throughout most of Southern California and part of central California. SoCalGas has one reportable segment. 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 the condensed consolidated financial statements of each Registrant. 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 September 30, 2024 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, 2023 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2023 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. Our Sempra Infrastructure segment includes the operating companies of our subsidiary, SI Partners, as well as certain holding companies and risk management activity. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. 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 September 30, 2024 and December 31, 2023. 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 $1,144 million and $1,166 million at September 30, 2024 and December 31, 2023, 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. Other Sempra Oncor Holdings 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 $15,160 million and $14,266 million at September 30, 2024 and December 31, 2023, respectively. 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 was $1,068 million at September 30, 2024 and $1,008 million at December 31, 2023. 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 $1,715 million and $1,580 million of assets at September 30, 2024 and December 31, 2023, 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 $1,060 million and $1,029 million of liabilities at September 30, 2024 and December 31, 2023, respectively, consisting primarily of long-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 $5,446 million and $3,927 million of assets at September 30, 2024 and December 31, 2023, respectively, 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 $865 million and $600 million of liabilities at September 30, 2024 and December 31, 2023, respectively, 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. CASH, CASH EQUIVALENTS AND RESTRICTED CASH 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. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) September 30, December 31, Sempra: Cash and cash equivalents $ 560 $ 236 Restricted cash, current 22 49 Restricted cash, noncurrent 108 104 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 690 $ 389 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. The implementation of customer assistance programs and higher 2023 winter season customer billings have resulted in certain SDG&E and SoCalGas customers exhibiting slower payment and higher levels of nonpayment than has been the case historically. In January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances. SDG&E and SoCalGas have regulatory mechanisms to recover credit losses and thus record changes in the allowances for credit losses related to Accounts Receivable – Trade that are probable of recovery in regulatory accounts. We discuss regulatory accounts in Note 4 below and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. Changes in allowances for credit losses for trade receivables and other receivables are as follows: CHANGES IN ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) 2024 2023 Sempra: Allowances for credit losses at January 1 $ 533 $ 181 Provisions for expected credit losses 149 374 Write-offs (169) (74) Allowances for credit losses at September 30 $ 513 $ 481 SDG&E: Allowances for credit losses at January 1 $ 144 $ 78 Provisions for expected credit losses 46 96 Write-offs (63) (34) Allowances for credit losses at September 30 $ 127 $ 140 SoCalGas: Allowances for credit losses at January 1 $ 331 $ 98 Provisions for expected credit losses 70 276 Write-offs (107) (40) Allowances for credit losses at September 30 $ 294 $ 334 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) September 30, December 31, 2024 2023 Sempra: Accounts receivable – trade, net $ 441 $ 480 Accounts receivable – other, net 57 52 Other long-term assets 15 1 Total allowances for credit losses $ 513 $ 533 SDG&E: Accounts receivable – trade, net $ 94 $ 116 Accounts receivable – other, net 26 27 Other long-term assets 7 1 Total allowances for credit losses $ 127 $ 144 SoCalGas: Accounts receivable – trade, net $ 255 $ 306 Accounts receivable – other, net 31 25 Other long-term assets 8 — Total allowances for credit losses $ 294 $ 331 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 September 30, 2024 and December 31, 2023, $5 million and $6 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 September 30, 2024 and December 31, 2023, $5 million of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets. TRANSACTIONS WITH AFFILIATES We summarize amounts due from and to unconsolidated affiliates at the Registrants in the following table. AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) September 30, December 31, Sempra: Tax sharing arrangement with Oncor Holdings $ 8 $ 25 Various affiliates 6 6 Total due from unconsolidated affiliates – current $ 14 $ 31 TAG Pipelines – 5.5% Note due January 9, 2024 (1) $ — $ (5) Total due to unconsolidated affiliates – current $ — $ (5) TAG Pipelines (1) : 5.5% Note due January 14, 2025 $ — $ (24) 5.5% Note due July 16, 2025 — (23) 5.5% Note due January 14, 2026 (8) (20) 5.5% Note due July 14, 2026 (12) (11) 5.5% Note due January 19, 2027 (15) (14) 5.5% Note due July 21, 2027 (18) (17) 5.5% Note due January 19, 2028 (47) — 5.5% Note due July 18, 2028 (41) — TAG Norte – 5.74% Note due December 17, 2029 (1) (206) (198) Total due to unconsolidated affiliates – noncurrent $ (347) $ (307) SDG&E: SoCalGas $ 8 $ — Total due from unconsolidated affiliates – current $ 8 $ — Sempra $ (40) $ (44) SoCalGas — (21) Various affiliates (8) (8) Total due to unconsolidated affiliates – current $ (48) $ (73) Income taxes due from Sempra (2) $ 251 $ 246 SoCalGas: SDG&E $ — $ 21 Various affiliates 2 1 Total due from unconsolidated affiliates – current $ 2 $ 22 Sempra $ (35) $ (38) SDG&E (8) — Total due to unconsolidated affiliates – current $ (43) $ (38) Income taxes due from Sempra (2) $ 9 $ 6 (1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding and VAT payable to the Mexican government. (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. We summarize income statement information from unconsolidated affiliates in the following table. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Revenues $ 11 $ 10 $ 31 $ 34 Interest expense 5 3 12 11 SDG&E: Revenues $ 6 $ 5 $ 17 $ 15 Cost of sales 36 25 111 82 SoCalGas: Revenues $ 43 $ 29 $ 124 $ 91 Cost of sales (1) (2) 2 (5) 37 (1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates. Guarantees Sempra provides guarantees related to Cameron LNG JV’s SDSRA and CFIN’s Support Agreement. We discuss these guarantees in Note 5. INVENTORIES The components of inventories are as follows: INVENTORY BALANCES (Dollars in millions) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Natural gas $ 166 $ 174 $ 1 $ 1 $ 153 $ 155 LNG 13 9 — — — — Materials and supplies 340 299 181 152 130 122 Total $ 519 $ 482 $ 182 $ 153 $ 283 $ 277 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 $585 million and $549 million at September 30, 2024 and December 31, 2023, respectively. WILDFIRE FUND In July 2019, the Wildfire Legislation was signed into law to address certain issues related to catastrophic wildfires in California and their impact on electric IOUs. We discuss the Wildfire Legislation further in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. SDG&E periodically evaluates the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in assumptions. In the second quarter of 2024, SDG&E revised its estimate of the period of benefit from 15 years to 25 years. SDG&E submitted its request to the OEIS for its annual wildfire safety certification in October 2024. OEIS has until January 2025 to issue the certification or provide written notice explaining why additional time is needed. SDG&E’s existing certification remains valid until this pending request is resolved. 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 September 30, 2024 and December 31, 2023, Other Long-Term Assets includes $345 million and $332 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, on Sempra’s Condensed Consolidated Balance Sheets. PROPERTY, PLANT AND EQUIPMENT Sempra Infrastructure’s Sonora natural gas pipeline consists of two pipeline 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. Sempra Infrastructure and the CFE have agreed to an amendment to their transportation services agreement and to re-route the portion of the pipeline that is in the Yaqui territory, whereby the CFE would pay for the re-routing with a new tariff. This amendment will terminate if certain conditions are not met, and Sempra Infrastructure retains the right to terminate the transportation services agreement and seek to recover its reasonable and documented costs and lost profit. Sempra Infrastructure continues to acquire and pursue the necessary rights-of-way and permits for the re-routed portion of the pipeline. At September 30, 2024, Sempra Infrastructure had $404 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if Sempra Infrastructure is unable to re-route a portion of the pipeline and resume operations or if Sempra Infrastructure terminates the contract and is unable to obtain recovery. 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra $ 166 $ 128 $ 466 $ 311 SDG&E 27 28 80 90 SoCalGas 25 20 75 55 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 September 30, 2024 and 2023 Sempra: Balance at June 30, 2024 $ (49) $ 35 $ (107) $ (121) OCI before reclassifications (12) (49) — (61) Amounts reclassified from AOCI — (5) 2 (3) Net OCI (12) (54) 2 (64) Balance at September 30, 2024 $ (61) $ (19) $ (105) $ (185) Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) OCI before reclassifications (5) 116 — 111 Amounts reclassified from AOCI (2) — (51) 1 (50) Net OCI (2) (5) 65 1 61 Balance at September 30, 2023 $ (43) $ 79 $ (96) $ (60) SDG&E: Balance at June 30, 2024 and September 30, 2024 $ (8) $ (8) Balance at June 30, 2023 and September 30, 2023 $ (7) $ (7) SoCalGas: Balance at June 30, 2024 and September 30, 2024 $ (10) $ (11) $ (21) Balance at June 30, 2023 and September 30, 2023 $ (11) $ (11) $ (22) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $(46) of financial instruments associated with sale of NCI to KKR Denali in 2023, which we discuss in Note 9 in “Noncontrolling Interests – SI Partners Subsidiaries.” 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 Nine months ended September 30, 2024 and 2023 Sempra: Balance at December 31, 2023 $ (36) $ 3 $ (117) $ (150) OCI before reclassifications (25) (1) 1 (25) Amounts reclassified from AOCI — (21) 11 (10) Net OCI (25) (22) 12 (35) Balance at September 30, 2024 $ (61) $ (19) $ (105) $ (185) Balance at December 31, 2022 $ (59) $ 10 $ (86) $ (135) OCI before reclassifications 16 129 (13) 132 Amounts reclassified from AOCI (2) — (60) 3 (57) Net OCI (2) 16 69 (10) 75 Balance at September 30, 2023 $ (43) $ 79 $ (96) $ (60) SDG&E: Balance at December 31, 2023 and September 30, 2024 $ (8) $ (8) Balance at December 31, 2022 and September 30, 2023 $ (7) $ (7) SoCalGas: Balance at December 31, 2023 $ (11) $ (12) $ (23) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at September 30, 2024 $ (10) $ (11) $ (21) Balance at December 31, 2022 $ (12) $ (12) $ (24) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at September 30, 2023 $ (11) $ (11) $ (22) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $(46) of financial instruments associated with sale of NCI to KKR Denali in 2023, which we discuss in Note 9 in “Noncontrolling Interests – SI Partners Subsidiaries.” 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 components Amounts reclassified Affected line item on Condensed Three months ended September 30, 2024 2023 Sempra: Financial instruments: Interest rate instruments $ (3) $ 1 Interest expense Interest rate instruments (5) (12) Equity earnings (1) Foreign exchange instruments (1) (1) Other income, net Foreign exchange instruments (1) (1) Equity earnings (1) Total, before income tax (10) (13) 3 2 Income tax benefit (expense) Total, net of income tax (7) (11) 2 6 Earnings attributable to noncontrolling interests Total, net of income tax and after NCI $ (5) $ (5) Pension and PBOP (2) : Amortization of actuarial loss $ 2 $ 1 Other income, net Amortization of prior service cost 1 1 Other income, net Total, before income tax 3 2 (1) (1) Income tax benefit (expense) Total, net of income tax $ 2 $ 1 Total reclassifications for the period, net of income tax and after NCI $ (3) $ (4) (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED) (Dollars in millions) Details about AOCI components Amounts reclassified Affected line item on Condensed Nine months ended September 30, 2024 2023 Sempra: Financial instruments: Interest rate instruments $ (9) $ 1 Interest expense Interest rate instruments (20) (33) Equity earnings (1) Foreign exchange instruments (5) — Revenues: Energy-related businesses (2) 1 Other income, net Foreign exchange instruments (5) 1 Equity earnings (1) Interest rate and foreign exchange instruments — (1) Interest expense — (6) Other income, net Total, before income tax (41) (37) 9 5 Income tax benefit (expense) Total, net of income tax (32) (32) 11 18 Earnings attributable to noncontrolling interests Total, net of income tax and after NCI $ (21) $ (14) Pension and PBOP (2) : Amortization of actuarial loss $ 5 $ 2 Other income, net Amortization of prior service cost 2 2 Other income, net Settlement charges 9 — Other income, net Total, before income tax 16 4 (5) (1) Income tax benefit (expense) Total, net of income tax $ 11 $ 3 Total reclassifications for the period, net of income tax and after NCI $ (10) $ (11) SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 Interest expense Pension and PBOP (2) : Amortization of prior service cost $ 1 $ 1 Other income (expense), net Total reclassifications for the period, net of income tax $ 2 $ 2 (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below). Reclassifications out of AOCI to net income were negligible in the three months and nine months ended September 30, 2024 and 2023 for SDG&E, and in the three months ended September 30, 2024 and 2023 for SoCalGas. 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 Other Income, Net. NET PERIODIC BENEFIT COST (Dollars in millions) Pension PBOP Three months ended September 30, 2024 2023 2024 2023 Sempra: Service cost $ 34 $ 25 $ 4 $ 3 Interest cost 41 39 9 9 Expected return on assets (40) (42) (19) (17) Amortization of: Prior service cost (credit) 1 2 (1) (1) Actuarial loss (gain) 4 3 (4) (5) Net periodic benefit cost (credit) 40 27 (11) (11) Regulatory adjustments 20 30 10 10 Total expense (income) recognized $ 60 $ 57 $ (1) $ (1) SDG&E

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	9 Months Ended
	Sep. 30, 2024
Accounting Changes and Error Corrections [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDS We describe below recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures. ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures”: ASU 2023-07 revises reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, public entities are required to disclose the title and position of the CODM and explain how the CODM uses the reported measures of profit or loss to assess segment performance. The standard also requires interim disclosure of certain segment-related disclosures that previously were required only on an annual basis. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. Entities must adopt the changes to the segment reporting disclosures on a retrospective basis. We plan to adopt the standard on December 31, 2024. ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures”: ASU 2023-09 improves the transparency of income tax disclosures by requiring disaggregated information about each Registrant’s ETR reconciliation as well as information on income taxes paid. For each annual period, each Registrant will be required to disclose specific categories in the rate reconciliation and provide additional information for reconciling items that meet a quantitative threshold (if the effect of those reconciling items is equal to or greater than 5% of the amount computed by multiplying pretax income or loss by the applicable statutory income tax rate). ASU 2023-09 is effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued. We plan to adopt the standard on December 31, 2025 and are currently evaluating the effect of the standard on our financial reporting. ASU 2024-03, “Disaggregation of Income Statement Expenses”: ASU 2024-03 mandates detailed disclosures on the disaggregation of income statement expenses. Public business entities are required to disclose in the notes to financial statements the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption. The standard also requires disclosure of the amount, and a qualitative description of, other items remaining in relevant expense captions that are not separately disaggregated. ASU 2024-03 is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. Early adoption is permitted, and entities may adopt the standard on either a prospective or retrospective basis. We are currently evaluating the effect of the standard on our financial reporting and have not yet selected the year in which we will adopt the standard.

REVENUES

REVENUES	9 Months Ended
	Sep. 30, 2024
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 tables disaggregate our revenues from contracts with customers by major service line and market. We also provide a reconciliation to total revenues by segment for Sempra. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) Sempra Sempra California Sempra Infrastructure Consolidating adjustments and Parent Sempra Three months ended September 30, 2024 By major service line: Utilities $ 2,394 $ 15 $ (7) $ 2,402 Energy-related businesses — 179 (12) 167 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 By market: Gas $ 1,237 $ 83 $ (6) $ 1,314 Electric 1,157 111 (13) 1,255 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 Utilities regulatory revenues (138) — — (138) Other revenues — 344 1 345 Total revenues $ 2,256 $ 538 $ (18) $ 2,776 Three months ended September 30, 2023 By major service line: Utilities $ 2,528 $ 18 $ (5) $ 2,541 Energy-related businesses — 369 (16) 353 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 By market: Gas $ 1,275 $ 234 $ (3) $ 1,506 Electric 1,253 153 (18) 1,388 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 Utilities regulatory revenues 197 — — 197 Other revenues — 242 1 243 Total revenues $ 2,725 $ 629 $ (20) $ 3,334 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) Sempra Sempra California Sempra Infrastructure Consolidating adjustments and Parent Sempra Nine months ended September 30, 2024 By major service line: Utilities $ 8,129 $ 63 $ (18) $ 8,174 Energy-related businesses — 625 (49) 576 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 By market: Gas $ 4,961 $ 356 $ (15) $ 5,302 Electric 3,168 332 (52) 3,448 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 Utilities regulatory revenues (107) — — (107) Other revenues — 778 6 784 Total revenues $ 8,022 $ 1,466 $ (61) $ 9,427 Nine months ended September 30, 2023 By major service line: Utilities $ 10,764 $ 67 $ (16) $ 10,815 Energy-related businesses — 916 (56) 860 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 By market: Gas $ 7,158 $ 605 $ (13) $ 7,750 Electric 3,606 378 (59) 3,925 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 Utilities regulatory revenues 76 — — 76 Other revenues — 1,502 (24) 1,478 Total revenues $ 10,840 $ 2,485 $ (96) $ 13,229 DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Three months ended September 30, 2024 2023 2024 2023 By major service line: Revenues from contracts with customers – Utilities $ 1,327 $ 1,438 $ 1,110 $ 1,120 By market: Gas $ 167 $ 182 $ 1,110 $ 1,120 Electric 1,160 1,256 — — Revenues from contracts with customers $ 1,327 $ 1,438 $ 1,110 $ 1,120 Revenues from contracts with customers $ 1,327 $ 1,438 $ 1,110 $ 1,120 Utilities regulatory revenues (84) 4 (56) 193 Total revenues $ 1,243 $ 1,442 $ 1,054 $ 1,313 Nine months ended September 30, 2024 2023 2024 2023 By major service line: Revenues from contracts with customers – Utilities $ 3,836 $ 4,603 $ 4,416 $ 6,252 By market: Gas $ 658 $ 988 $ 4,416 $ 6,252 Electric 3,178 3,615 — — Revenues from contracts with customers $ 3,836 $ 4,603 $ 4,416 $ 6,252 Revenues from contracts with customers $ 3,836 $ 4,603 $ 4,416 $ 6,252 Utilities regulatory revenues 141 (246) (248) 322 Total revenues $ 3,977 $ 4,357 $ 4,168 $ 6,574 REVENUES FROM CONTRACTS WITH CUSTOMERS Remaining Performance Obligations For contracts greater than one year, at September 30, 2024, 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 for contracts greater than one year at September 30, 2024. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2024 (excluding first nine months of 2024) $ 90 $ — 2025 321 4 2026 321 4 2027 321 4 2028 253 4 Thereafter 2,313 56 Total revenues to be recognized $ 3,619 $ 72 (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 nine months ended September 30, 2024 or 2023. Sempra Infrastructure recorded a contract liability for funds held as collateral in lieu of a customer’s letters of credit primarily associated with its LNG storage and regasification agreement. CONTRACT LIABILITIES (Dollars in millions) 2024 2023 Sempra: Contract liabilities at January 1 $ (198) $ (252) Revenue from performance obligations satisfied during reporting period 5 9 Payments received in advance (3) (21) Contract liabilities at September 30 (1) $ (196) $ (264) SDG&E: Contract liabilities at January 1 $ (75) $ (79) Revenue from performance obligations satisfied during reporting period 3 3 Contract liabilities at September 30 (2) $ (72) $ (76) (1) Balances at September 30, 2024 include $4 in Other Current Liabilities and $192 in Deferred Credits and Other. (2) Balances at September 30, 2024 include $3 in Other Current Liabilities and $69 in Deferred Credits and Other. Receivables from Revenues from Contracts with Customers The table below shows receivable balances, net of allowances for credit losses, associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) September 30, 2024 December 31, 2023 Sempra: Accounts receivable – trade, net (1) $ 1,490 $ 1,951 Accounts receivable – other, net 20 15 Due from unconsolidated affiliates – current (2) 4 4 Other long-term assets (3) 20 — Total $ 1,534 $ 1,970 SDG&E: Accounts receivable – trade, net (1) $ 867 $ 870 Accounts receivable – other, net 19 13 Due from unconsolidated affiliates – current (2) 7 6 Other long-term assets (3) 6 — Total $ 899 $ 889 SoCalGas: Accounts receivable – trade, net $ 557 $ 985 Accounts receivable – other, net 1 2 Other long-term assets (3) 14 — Total $ 572 $ 987 (1) At September 30, 2024 and December 31, 2023, includes $223 and $148, respectively, of receivables due from customers that were billed on behalf of Community Choice Aggregators, 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 January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances.

REGULATORY MATTERS

REGULATORY MATTERS	9 Months Ended
	Sep. 30, 2024
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES 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) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Fixed-price contracts and other derivatives $ 54 $ 215 $ 8 $ 14 $ 46 $ 201 Deferred income taxes recoverable in rates 1,526 1,142 780 626 660 430 Pension and PBOP plan obligations (255) (212) 51 48 (306) (260) Employee benefit costs 24 24 3 3 21 21 Removal obligations (3,261) (3,082) (2,650) (2,468) (611) (614) Environmental costs 148 139 115 105 33 34 Sunrise Powerlink fire mitigation 123 124 123 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (223) (233) (223) (233) — — Commodity – gas, including transportation (179) (259) 46 52 (225) (311) Safety and reliability 1,192 959 276 207 916 752 Public purpose programs (442) (273) (200) (144) (242) (129) Wildfire mitigation plan 811 685 811 685 — — Liability insurance premium 107 113 79 90 28 23 Other balancing accounts 306 373 (70) (152) 376 525 Other regulatory (liabilities) assets, net (2) (188) (10) (5) 49 (181) (58) Total $ (257) $ (295) $ (856) $ (994) $ 515 $ 614 (1) At September 30, 2024 and December 31, 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $2,090 and $1,913, respectively, for SDG&E was $979 and $950, respectively, and for SoCalGas was $1,111 and $963, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. 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. On October 18, 2024, the CPUC issued a proposed decision in the 2024 GRC for SDG&E’s and SoCalGas’ test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. The 2024 GRC proposed decision adopts a 2024 test year revenue requirement of $2,800 million for SDG&E’s combined operations ($2,198 million for its electric operations and $602 million for its natural gas operations), which is $207 million lower than the $3,007 million that SDG&E had requested in its updated application. The proposed 2024 combined revenue requirement, if adopted, represents an increase of $267 million (10.5%) compared to its authorized 2023 combined revenue requirement. The proposed post-test year revenue requirement, if adopted, would be annual increases of approximately 3.9% for 2025-2027 at SDG&E. The 2024 GRC proposed decision adopts a 2024 test year revenue requirement of $4,062 million for SoCalGas, which is $372 million lower than the $4,434 million that SoCalGas had requested in its May 2022 application. The proposed 2024 revenue requirement, if adopted, represents an increase of $523 million (14.8%) over its authorized 2023 revenue requirement. The proposed post-test year revenue requirement, if adopted, would be annual increases of approximately 3.9% for 2025-2027 at SoCalGas. Because a final decision for the 2024 GRC was not issued by September 30, 2024, SDG&E and SoCalGas recorded CPUC-authorized base revenues in the three months and nine months ended September 30, 2024 based on 2023 levels authorized under the 2019 GRC. The impact of the final decision, retroactive to January 1, 2024, as authorized by the CPUC, will be reflected in SDG&E’s and SoCalGas’ financial statements in the period in which the final decision is issued. We expect the CPUC to issue a final decision by the end of this year. 2024 GRC Track 2 In October 2023, SDG&E submitted a separate request to the CPUC in its 2024 GRC, known as a Track 2 request. This request seeks review and recovery of $1.5 billion of wildfire mitigation plan costs incurred from 2019 through 2022 that were in addition to amounts authorized in the 2019 GRC. SDG&E expects to receive a proposed reasonableness review decision for its Track 2 request in the first half of 2025. Revenues associated with the Track 2 request amounts described above have been recorded in a regulatory account. In February 2024, the CPUC approved an interim cost recovery mechanism that would permit SDG&E to recover in rates $194 million and $96 million of this regulatory account balance in 2024 and 2025, respectively. Such recovery of SDG&E’s wildfire mitigation plan regulatory account balance will be subject to refund, contingent on the reasonableness review decision for its Track 2 request. 2024 GRC Track 3 SDG&E expects to submit in the first half of 2025 an additional request to the CPUC in its 2024 GRC, known as a Track 3 request, for review and recovery of its 2023 wildfire mitigation plan costs. 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 was to remain in effect through December 31, 2025, subject to the CCM. AUTHORIZED COST OF CAPITAL FOR 2023 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. On September 30, 2023, the CCM was triggered for SDG&E and SoCalGas. In December 2023, the CPUC approved the following authorized rates of return effective January 1, 2024. AUTHORIZED COST OF CAPITAL FOR 2024 SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.34 % 1.96 % Long-Term Debt 45.60 % 4.54 % 2.07 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.65 5.54 Common Equity 52.00 10.50 5.46 100.00 % 7.67 % 100.00 % 7.67 % In October 2023, the CPUC issued a ruling to initiate a second phase of the 2023-2025 cost of capital proceeding to evaluate potential modifications to the CCM. In October 2024, the CPUC issued a final decision to modify the CCM. The final decision reduces the upward or downward adjustment to authorized ROE, if the CCM is triggered, to 20% of the change in the benchmark rate during the measurement period from the current 50%. The final decision adopts this change effective January 1, 2025, reducing both SDG&E’s and SoCalGas’ ROE by 42 bps to 10.23% and 10.08%, respectively, and allowing SDG&E and SoCalGas to update their respective costs of preferred equity and debt for 2025. SDG&E and SoCalGas intend to file advice letters in November 2024 to address the implementation, subject to approval, of the updated cost of capital. FERC RATE MATTERS SDG&E files separately with the FERC for its authorized transmission revenue requirement and ROE on FERC-regulated electric transmission operations and assets. SDG&E’s currently effective TO5 settlement provides for an 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). In May 2024, the CPUC and other parties filed a petition and complaint with the FERC seeking an order that directs SDG&E to remove the California ISO adder from its currently effective TO5 settlement and refund the California ISO adder retroactively from June 1, 2019. In June 2024, SDG&E exercised its right to terminate the TO5 settlement. Accordingly, in October 2024, SDG&E submitted its TO6 filing to the FERC to be effective January 1, 2025, subject to refund. SDG&E’s TO6 filing proposes, among other items, an increase to SDG&E’s currently authorized base ROE from 10.10% to 11.75% and continuation of the California ISO adder. SDG&E expects further proceedings on these two matters. 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 be completed around 2030. 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 2023, the CPUC granted SDG&E authorization to access NDT funds of up to $79 million for forecasted 2024 costs. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E 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 September 30, 2024 Short-term investments, primarily cash equivalents $ 18 $ — $ — $ 18 Equity securities 80 241 (2) 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 69 1 — 70 Municipal bonds (2) 290 3 (6) 287 Other securities (3) 233 4 (6) 231 Total debt securities 592 8 (12) 588 Receivables (payables), net (19) — — (19) Total $ 671 $ 249 $ (14) $ 906 December 31, 2023 Short-term investments, primarily cash equivalents $ 21 $ — $ — $ 21 Equity securities 89 225 (2) 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 50 2 (1) 51 Municipal bonds 280 3 (8) 275 Other securities 228 3 (11) 220 Total debt securities 558 8 (20) 546 Receivables (payables), net (7) — — (7) Total $ 661 $ 233 $ (22) $ 872 (1) Maturity dates are 2025 - 2055. (2) Maturity dates are 2024 - 2062. (3) Maturity dates are 2024 - 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Proceeds from sales $ 259 $ 143 $ 639 $ 437 Gross realized gains 17 12 41 20 Gross realized losses 2 3 7 9 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 $480 million at September 30, 2024 and is based on a cost study prepared in 2020, which the CPUC approved in August 2024. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $500 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $60 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $500 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed a negligible amount for retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

SEMPRA - INVESTMENTS IN UNCONSO

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES	9 Months Ended
	Sep. 30, 2024
Investments [Abstract]
SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES	SEMPRA – 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. Distributions received from equity method investees are classified in the Condensed Consolidated Statements of Cash Flows as either a return on investment in operating activities or a return of investment in investing activities based on the “nature of the distribution” approach. See Note 12 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. 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-fencing 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 nine months ended September 30, 2024 and 2023, Sempra contributed $578 million and $270 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $314 million and $323 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Operating revenues $ 1,660 $ 1,592 $ 4,610 $ 4,227 Operating expenses (1,109) (1,007) (3,203) (3,007) Income from operations 551 585 1,407 1,220 Interest expense (170) (140) (481) (396) Income tax expense (75) (81) (179) (148) Net income 320 376 791 672 NCI held by Texas Transmission Investment LLC (63) (75) (157) (135) Earnings attributable to Sempra (1) 257 301 634 537 (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. CAMERON LNG JV In the nine months ended September 30, 2024 and 2023, Sempra Infrastructure contributed $10 million and $11 million, respectively, to Cameron LNG JV, and Cameron LNG JV distributed $353 million and $339 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 $18 million at September 30, 2024, 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 are 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 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 September 30, 2024, the fair value of the Support Agreement was $24 million, of which $7 million is included in Other Current Assets and $17 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet. TAG NORTE In the nine months ended September 30, 2024 and 2023, TAG Norte distributed $62 million and $36 million, respectively, to Sempra Infrastructure. IMG In the nine months ended September 30, 2023, IMG distributed $6 million to Sempra Infrastructure.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	9 Months Ended
	Sep. 30, 2024
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 September 30, 2024, Sempra had an aggregate capacity of $9.9 billion under seven primary committed lines of credit, which provide liquidity and support our commercial paper programs. Because our commercial paper programs are supported by 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) September 30, 2024 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2029 (1) $ 4,000 $ (350) $ — $ — $ 3,650 SDG&E October 2029 (1) 1,500 (384) — — 1,116 SoCalGas October 2029 (1) 1,200 — — — 1,200 SI Partners and IEnova September 2025 500 — (390) — 110 SI Partners and IEnova August 2026 1,000 — — — 1,000 SI Partners and IEnova August 2028 1,500 — (551) — 949 Port Arthur LNG March 2030 200 — — (64) 136 Total $ 9,900 $ (734) $ (941) $ (64) $ 8,161 (1) In October 2024, Sempra, SDG&E and SoCalGas each amended their respective credit facility to extend the expiration date from October 2028 to October 2029. 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 September 30, 2024, each Registrant was in compliance with this ratio under its respective credit facility. The three lines of credit that are shared by SI Partners and IEnova require that SI Partners maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in each credit facility) of no more than 5.25 to 1.00 at the end of each quarter. At September 30, 2024, SI Partners was in compliance with this ratio. Uncommitted Line of Credit ECA LNG Phase 1 has an uncommitted line of credit, which is generally used for working capital requirements. Borrowings can be in U.S. dollars or Mexican pesos. At September 30, 2024, an aggregate of $14 million, before reductions of any unamortized discounts, was outstanding, which were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus the applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on the one-month or three-month SOFR plus the applicable margin and a credit adjustment spread of 10 bps. In August 2024, the facility was amended to decrease the capacity from $200 million to $100 million, extend the expiration date to August 2026, and adjust the applicable margin to 154 bps for amounts borrowed in Mexican pesos and 164 bps for amounts borrowed in U.S. dollars. 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 September 30, 2024, we had $491 million in standby letters of credit outstanding under these agreements. UNCOMMITTED LETTERS OF CREDIT OUTSTANDING (Dollars in millions) Expiration date range September 30, 2024 SDG&E January 2025 - November 2025 $ 26 SoCalGas October 2024 - November 2025 20 Other Sempra October 2024 - November 2054 445 Total Sempra $ 491 Term Loan In May 2024, SoCalGas entered into a $500 million, 364-day term loan facility with a maturity date of May 22, 2025. Upon execution, SoCalGas borrowed $300 million, net of negligible debt issuance costs, under the term loan facility and borrowed the remaining $200 million in August 2024. SoCalGas may request an increase in the term loan facility of up to $500 million prior to the maturity date, subject to lender approval. The outstanding borrowings bear interest at a per annum rate equal to term SOFR, plus 80 bps and a credit adjustment spread of 10 bps. SoCalGas used the proceeds to repay commercial paper and for other general corporate purposes. At September 30, 2024, the term loan is included in Short-Term Debt on SoCalGas’ Condensed Consolidated Balance Sheet. Weighted-Average Interest Rates The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES September 30, 2024 December 31, 2023 Sempra 5.54 % 5.96 % SDG&E 4.95 — SoCalGas 5.82 5.44 LONG-TERM DEBT SDG&E In March 2024, SDG&E issued $600 million aggregate principal amount of 5.55% first mortgage bonds due in full upon maturity on April 15, 2054 and received proceeds of $587 million (net of debt discount, underwriting discounts and debt issuance costs of $13 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 to repay commercial paper and for other general corporate purposes. SoCalGas In March 2024, SoCalGas issued $500 million aggregate principal amount of 5.60% first mortgage bonds due in full upon maturity on April 1, 2054 and received proceeds of $491 million (net of debt discount, underwriting discounts and debt issuance costs of $9 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SoCalGas used the net proceeds to repay outstanding indebtedness and for other general corporate purposes. In August 2024, SoCalGas issued $600 million aggregate principal amount of 5.05% first mortgage bonds due in full upon maturity on September 1, 2034 and received proceeds of $592 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SoCalGas used the net proceeds to repay outstanding indebtedness and for other general corporate purposes. Other Sempra Sempra In March 2024 and May 2024, Sempra issued $600 million and $500 million, respectively, of 6.875% fixed-to-fixed reset rate junior subordinated notes maturing on October 1, 2054. In March 2024, we received proceeds of $593 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). In May 2024, we received proceeds of $489 million (net of debt discount, underwriting discounts and debt issuance costs of $11 million, but excluding $7 million paid to us in respect of accrued interest from and including March 14, 2024 to, but excluding, May 31, 2024). In September 2024, Sempra issued $1.25 billion of 6.40% fixed-to fixed reset rate junior subordinated notes maturing on October 1, 2054, and we received proceeds of $1.235 billion (net of debt discounts, underwriting discounts and debt issuance costs of $15 million). We used, or plan to use, the proceeds from the offerings for general corporate purposes, including repayment of commercial paper and other indebtedness. Interest on the notes accrues from and including March 14, 2024 (for the March 2024 and May 2024 issuances) and September 9, 2024 (for the September 2024 issuance) and is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on October 1, 2024 (for the March 2024 and May 2024 issuances) and April 1, 2025 (for the September 2024 issuance). The notes bear interest, as follows: ▪ from and including March 14, 2024 to, but excluding, October 1, 2029 at the rate of 6.875% per annum (for the March 2024 and May 2024 issuances), and from and including September 9, 2024 to, but excluding, October 1, 2034 at the rate of 6.40% per annum (for the September 2024 issuance); and ▪ from and including October 1, 2029 (for the March 2024 and May 2024 issuances) and October 1, 2034 (for the September 2024 issuance), during each subsequent five-year period beginning on October 1 of every fifth year, at a rate per annum equal to the Five-year U.S. Treasury Rate (as defined in the notes) as of the day falling two business days before the first day of such five-year period plus a spread of 2.789% (for the March 2024 and May 2024 issuances) and 2.632% (for the September 2024 issuance), to be reset on October 1 of every fifth year beginning in 2029 (for the March 2024 and May 2024 issuances) and 2034 (for the September 2024 issuance). We may redeem some or all of the notes before their maturity, as follows: ▪ in whole or in part, (i) on any day in the period commencing on the date falling 90 days prior to, and ending on and including October 1, 2029 (for the March 2024 and May 2024 issuances) and October 1, 2034 (for the September 2024 issuance), and (ii) after those respective dates, on any interest payment date, at a redemption price in cash equal to 100% of the principal amount of the notes being redeemed, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to be redeemed to, but excluding, the redemption date; ▪ in whole but not in part, at any time following the occurrence and during the continuance of a tax event (as defined in the notes) at a redemption price in cash equal to 100% of the principal amount of the notes, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to, but excluding, the redemption date; and ▪ in whole but not in part, at any time following the occurrence and during the continuance of a rating agency event (as defined in the notes) at a redemption price in cash equal to 102% of the principal amount of the notes, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to, but excluding, the redemption date. The notes described above are unsecured obligations and rank junior and subordinate in right of payment to our existing and future senior indebtedness. The notes rank equally in right of payment with each other and with our existing 4.125% fixed-to-fixed reset rate junior subordinated notes due 2052 and 5.75% junior subordinated notes due 2079 and with any future unsecured indebtedness that we may incur if the terms of such indebtedness provide that it ranks equally with the notes in right of payment. The notes are effectively subordinated in right of payment to any secured indebtedness we have incurred or may incur (to the extent of the value of the collateral securing such secured indebtedness) and to all existing and future indebtedness and other liabilities and any preferred equity of our subsidiaries. ECA LNG Phase 1 ECA LNG Phase 1 has a five-year loan agreement with a syndicate of seven external lenders that matures on December 9, 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 September 30, 2024 and December 31, 2023, $1.0 billion and $832 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 7.56% and 8.31%, respectively. Port Arthur LNG Port Arthur LNG has a seven-year term loan facility agreement with a syndicate of lenders that matures on March 20, 2030 for an aggregate principal amount of approximately $6.8 billion. At September 30, 2024 and December 31, 2023, $420 million and $258 million, respectively, of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.33% and 5.81%, respectively.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2024
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 contracts that otherwise would have been accounted for as 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 September 30, 2024 December 31, 2023 Sempra: Natural gas MMBtu 455 361 Electricity MWh — 1 Congestion revenue rights MWh 16 36 SDG&E: Natural gas MMBtu 18 17 Congestion revenue rights MWh 16 36 SoCalGas: Natural gas MMBtu 405 268 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 March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps maturing in 2048, which were designated as cash flow hedges. On September 30, 2024, Port Arthur LNG voluntarily de-designated those interest rate swaps that begin hedging interest payments in March 2026 to provide for future financing flexibility. At the time of de-designation, $40 million of deferred gains related to the de-designated notional amount were included in AOCI, which will remain in AOCI until the hedged interest payments impact earnings or such hedged interest payments become probable of not occurring. In October 2024, Port Arthur LNG received a cash settlement of $46 million, net of transaction costs, for the termination of $1.0 billion of the notional amount of both the designated and de-designated interest rate swaps, with the associated deferred gains remaining in AOCI. The following table presents the notional amounts of our interest rate derivatives, excluding those in our equity method investments. INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Cash flow hedges (1) $ 3,571 2024-2034 $ 4,451 2024-2048 Undesignated derivatives (2) 4,163 2026-2048 — — (1) At September 30, 2024, cash flow hedges include Port Arthur LNG interest rate swaps with a maximum notional amount of $3,286 that mature in March 2026. At September 30, 2024 and December 31, 2023, cash flow hedges accrued interest based on a notional amount of $1,422 and $488, respectively. (2) At September 30, 2024, undesignated derivatives consist of Port Arthur LNG de-designated interest rate swaps with a maximum notional amount of $4,163 that begin hedging interest payments in March 2026. 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. In May 2024, Oncor entered into cross-currency swaps designated as fair value hedges intended to offset foreign currency exchange rate risk related to its Euro-denominated debt. 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 notional amounts of our foreign currency derivatives, excluding those in our equity method investments. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Foreign currency derivatives $ 201 2024-2026 $ 176 2024-2025 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. We discuss the fair value of derivative assets and liabilities in Note 8. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2024 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 $ 14 $ 23 $ — $ (3) Foreign exchange instruments 5 1 (1) — Derivatives not designated as hedging instruments: Interest rate instruments — 40 — — Commodity contracts not subject to rate recovery 22 37 (17) (47) Associated offsetting commodity contracts (14) (26) 14 26 Commodity contracts subject to rate recovery 5 7 (52) (14) Associated offsetting commodity contracts (2) (3) 2 3 Associated offsetting cash collateral — — 9 5 Net amounts presented on the balance sheet 30 79 (45) (30) Additional cash collateral for commodity contracts not subject to rate recovery 55 — — — Additional cash collateral for commodity contracts subject to rate recovery 26 — — — Total (2) $ 111 $ 79 $ (45) $ (30) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ 7 $ (11) $ (8) Associated offsetting commodity contracts (1) (3) 1 3 Associated offsetting cash collateral — — 9 5 Net amounts presented on the balance sheet 3 4 (1) — Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (2) $ 27 $ 4 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 1 $ — $ (41) $ (6) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet — — (40) (6) Additional cash collateral for commodity contracts subject to rate recovery 2 — — — Total $ 2 $ — $ (40) $ (6) (1) Included in Other Current Assets for SDG&E and 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, 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 $ 17 $ 70 $ — $ — Foreign exchange instruments — — (9) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 173 52 (170) (56) Associated offsetting commodity contracts (169) (51) 169 51 Commodity contracts subject to rate recovery 10 8 (228) (9) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 12 7 Net amounts presented on the balance sheet 26 77 (221) (5) Additional cash collateral for commodity contracts not subject to rate recovery 74 — — — Additional cash collateral for commodity contracts subject to rate recovery 22 — — — Total (2) $ 122 $ 77 $ (221) $ (5) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 9 $ 8 $ (18) $ (9) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 12 7 Net amounts presented on the balance sheet 4 6 (1) — Additional cash collateral for commodity contracts subject to rate recovery 21 — — — Total (2) $ 25 $ 6 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 1 $ — $ (210) $ — Net amounts presented on the balance sheet 1 — (210) — Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 2 $ — $ (210) $ — (1) Included in Other Current Assets for SDG&E and SoCalGas. (2) Normal purchase contracts previously measured at fair value are excluded. The following table includes the effects of derivative instruments designated as hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI. HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain Pretax gain (loss) reclassified Three months ended September 30, Three months ended September 30, 2024 2023 Location 2024 2023 Sempra: Cash flow hedges: Interest rate instruments $ (203) $ 320 Interest expense $ 3 $ (1) Interest rate instruments (33) 32 Equity earnings (1) 5 12 Foreign exchange instruments 2 8 Other income, net 1 1 Foreign exchange instruments 2 7 Equity earnings (1) 1 1 Fair value hedges: Foreign exchange instruments (3) — Equity earnings (1) — — Total $ (235) $ 367 $ 10 $ 13 Nine months ended September 30, Nine months ended September 30, 2024 2023 Location 2024 2023 Sempra: Cash flow hedges: Interest rate instruments $ 5 $ 337 Interest expense $ 9 $ (1) Interest rate instruments (8) 56 Equity earnings (1) 20 33 Foreign exchange instruments 14 — Revenues: Energy- related businesses 5 — Other income, net 2 (1) Foreign exchange instruments 12 1 Equity earnings (1) 5 (1) Interest rate and foreign exchange instruments — 7 Interest expense — 1 Other income, net — 6 Fair value hedges: Foreign exchange instruments (10) — Equity earnings (1) — — Total $ 13 $ 401 $ 41 $ 37 SoCalGas: Cash flow hedges: Interest rate instruments $ — $ — Interest expense $ (1) $ (1) (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax. For Sempra, we expect that net gains before NCI of $31 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $11 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. At September 30, 2024, t he maximum length of time over which Sempra is hedging its exposure to the variability in future cash flows for forecasted transactions, excluding those forecasted transactions related to the payment of variable interest on existing financial instruments, is approximately 1.5 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 September 30, Nine months ended Location 2024 2023 2024 2023 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-related businesses $ 98 $ 83 $ 218 $ 785 Commodity contracts subject to rate recovery Cost of natural gas (16) (125) (43) (172) Commodity contracts subject to rate recovery Cost of electric fuel and purchased power (10) 23 (29) 5 Interest rate instrument Interest expense — — — (47) Total $ 72 $ (19) $ 146 $ 571 SDG&E: Commodity contracts subject to rate recovery Cost of electric fuel and purchased power $ (10) $ 23 $ (29) $ 5 SoCalGas: Commodity contracts subject to rate recovery Cost of natural gas $ (16) $ (125) $ (43) $ (172) 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 September 30, 2024 and December 31, 2023 was $114 million and $215 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at September 30, 2024 and December 31, 2023 was $46 million and $210 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at September 30, 2024 or December 31, 2023. At September 30, 2024, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $114 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	9 Months Ended
	Sep. 30, 2024
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 tables below set forth our financial assets and liabilities, by level within the fair value hierarchy, that were accounted for at fair value on a recurring basis at September 30, 2024 and December 31, 2023. 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, 2023. 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 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 – Other Sempra.” RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 15 $ 3 $ — $ 18 Equity securities 315 4 — 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 45 25 — 70 Municipal bonds — 287 — 287 Other securities — 231 — 231 Total debt securities 45 543 — 588 Total nuclear decommissioning trusts (2) 375 550 — 925 Short-term investments held in Rabbi Trust 59 — — 59 Support Agreement, net of related guarantee fees — — 24 24 Interest rate instruments — 77 — $ — 77 Foreign exchange instruments — 6 — — 6 Commodity contracts not subject to rate recovery 6 53 — 15 74 Commodity contracts subject to rate recovery 4 2 6 21 33 Total $ 444 $ 688 $ 30 $ 36 $ 1,198 Liabilities: Interest rate instruments $ — $ 3 $ — $ — $ 3 Foreign exchange instruments — 1 — — 1 Commodity contracts not subject to rate recovery — 64 — (40) 24 Commodity contracts subject to rate recovery 18 48 — (19) 47 Total $ 18 $ 116 $ — $ (59) $ 75 Fair value at December 31, 2023 Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 19 $ 2 $ — $ 21 Equity securities 308 4 — 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 34 17 — 51 Municipal bonds — 275 — 275 Other securities — 220 — 220 Total debt securities 34 512 — 546 Total nuclear decommissioning trusts (2) 361 518 — 879 Short-term investments held in Rabbi Trust 67 — — 67 Support Agreement, net of related guarantee fees — — 23 23 Interest rate instruments — 87 — $ — 87 Commodity contracts not subject to rate recovery — 5 — 74 79 Commodity contracts subject to rate recovery — 1 10 22 33 Total $ 428 $ 611 $ 33 $ 96 $ 1,168 Liabilities: Foreign exchange instruments $ — $ 9 $ — $ — $ 9 Commodity contracts not subject to rate recovery — 6 — — 6 Commodity contracts subject to rate recovery 20 210 — (19) 211 Total $ 20 $ 225 $ — $ (19) $ 226 (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. (2) Excludes receivables (payables), net. RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 15 $ 3 $ — $ 18 Equity securities 315 4 — 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 45 25 — 70 Municipal bonds — 287 — 287 Other securities — 231 — 231 Total debt securities 45 543 — 588 Total nuclear decommissioning trusts (2) 375 550 — 925 Commodity contracts subject to rate recovery 4 1 6 $ 20 31 Total $ 379 $ 551 $ 6 $ 20 $ 956 Liabilities: Commodity contracts subject to rate recovery $ 18 $ 1 $ — $ (18) $ 1 Fair value at December 31, 2023 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 19 $ 2 $ — $ 21 Equity securities 308 4 — 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 34 17 — 51 Municipal bonds — 275 — 275 Other securities — 220 — 220 Total debt securities 34 512 — 546 Total nuclear decommissioning trusts (2) 361 518 — 879 Commodity contracts subject to rate recovery — — 10 $ 21 31 Total $ 361 $ 518 $ 10 $ 21 $ 910 Liabilities: Commodity contracts subject to rate recovery $ 20 $ — $ — $ (19) $ 1 (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. (2) Excludes receivables (payables), net. RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 SoCalGas: Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 47 $ — $ (1) $ 46 Fair value at December 31, 2023 SoCalGas: Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 210 $ — $ — $ 210 (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 classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) Three months ended September 30, 2024 2023 Balance at July 1 $ 6 $ 20 Realized and unrealized gains (losses), net (3) (2) Allocated transmission instruments 1 1 Settlements 2 (1) Balance at September 30 $ 6 $ 18 Change in unrealized gains relating to instruments still held at September 30 $ — $ 1 Nine months ended September 30, 2024 2023 Balance at January 1 $ 10 $ 35 Realized and unrealized gains (losses), net (6) (10) Allocated transmission instruments 1 (1) Settlements 1 (6) Balance at September 30 $ 6 $ 18 Change in unrealized losses relating to instruments still held at September 30 $ (1) $ (8) (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. Inputs used to determine the fair value of CRRs 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 2024 $ (3.69) to $ 9.55 $ (0.44) 2023 (3.09) to 10.71 (0.56) 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. 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. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Other Sempra 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. LEVEL 3 RECONCILIATIONS (Dollars in millions) Three months ended September 30, 2024 2023 Balance at July 1 $ 23 $ 23 Realized and unrealized gains (losses), net (1) 3 (3) Settlements (2) (2) Balance at September 30 (2) $ 24 $ 18 Change in unrealized gains (losses) relating to instruments still held at September 30 $ 3 $ (2) Nine months ended September 30, 2024 2023 Balance at January 1 $ 23 $ 17 Realized and unrealized gains (losses), net (1) 7 7 Settlements (6) (6) Balance at September 30 (2) $ 24 $ 18 Change in unrealized gains relating to instruments still held at September 30 $ 6 $ 7 (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 $17 in Other Long-term Assets at September 30, 2024 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, current and noncurrent accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, dividends and accounts payable due in one year or less, 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 September 30, 2024 Sempra: Long-term note receivable (1) $ 347 $ — $ — $ 339 $ 339 Long-term amounts due to unconsolidated affiliates 347 — 326 — 326 Total long-term debt (2) 31,224 — 29,765 — 29,765 SDG&E: Total long-term debt (3) $ 8,950 $ — $ 8,247 $ — $ 8,247 SoCalGas: Total long-term debt (4) $ 7,359 $ — $ 7,220 $ — $ 7,220 December 31, 2023 Sempra: Long-term note receivable (1) $ 334 $ — $ — $ 318 $ 318 Long-term amounts due to unconsolidated affiliates 312 — 283 — 283 Total long-term debt (2) 27,716 — 25,617 — 25,617 SDG&E: Total long-term debt (3) $ 8,750 $ — $ 7,856 $ — $ 7,856 SoCalGas: Total long-term debt (4) $ 6,759 $ — $ 6,442 $ — $ 6,442 (1) Before allowances for credit losses of $5 and $6 at September 30, 2024 and December 31, 2023, respectively. Excludes unamortized transaction costs of $3 and $4 at September 30, 2024 and December 31, 2023, respectively. (2) After the effects of interest rate swaps. Before reductions of unamortized discount and debt issuance costs of $366 and $322 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,318 and $1,340 at September 30, 2024 and December 31, 2023, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $97 and $89 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,209 and $1,233 at September 30, 2024 and December 31, 2023, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $68 and $55 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $109 and $107 at September 30, 2024 and December 31, 2023, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 10.

SEMPRA - EQUITY AND EARNINGS PE

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE	9 Months Ended
	Sep. 30, 2024
Earnings Per Share [Abstract]
SEMPRA – EQUITY AND EARNINGS PER COMMON SHARE	SEMPRA – EQUITY AND EARNINGS PER COMMON SHARE PREFERRED STOCK On May 2, 2024, Sempra filed an amendment to its amended and restated articles of incorporation to implement the revocation of the series A preferred stock and series B preferred stock, all of which had previously been converted to Sempra common stock, thereby decreasing the number of authorized shares of series A preferred stock from 17,250,000 to zero and series B preferred stock from 5,750,000 to zero. Effective as of May 2, 2024, each such series of stock is no longer an authorized series of Sempra’s capital stock. 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 such shareholder of record received one additional share of Sempra common stock for every then-held share of Sempra common stock, which was distributed after the close of trading on August 21, 2023. Sempra’s common stock began trading on a post-split basis effective August 22, 2023. Sempra’s common stock continues to have no par value with 1,125,000,000 authorized shares. Except as expressly noted, all share and per share information related to issued and outstanding common stock and outstanding equity awards with respect to common stock has been retroactively adjusted to reflect the stock split and is presented on a post-split basis herein. COMMON STOCK OFFERINGS ATM Program On November 6, 2024, we established an ATM program, providing for the offer and sale of shares of Sempra common stock having an aggregate gross sales price of up to $3.0 billion through agents acting as our sales agents or as forward sellers or directly to the agents as principals. The shares may be offered and sold in amounts and at times to be determined by us from time to time. The agents will be entitled to a commission that will not exceed 1.0% of the gross sales price of all shares sold through it as agent pursuant to the sales agreement. Under the ATM program, we may enter into separate forward sale agreements with affiliates of the agents as forward purchasers. We expect to fully physically settle each forward sale agreement, if any. However, we will generally have the right, subject to certain exceptions, to elect to cash settle or net share settle all or any portion of our obligations under any such forward sale agreement. If we enter into a forward sale agreement with any forward purchaser, we expect that such forward purchaser (or its affiliate) will attempt to borrow from third parties and sell, through the relevant agent acting, as sales agent for such forward purchaser, shares of our common stock to hedge such forward purchaser’s exposure under such forward sale agreement. We will not receive any proceeds from any sale of shares borrowed by a forward purchaser (or its affiliate) and sold through a forward seller. The forward seller will receive a commission, in the form of a reduction to the initial forward price under the related forward sale agreement, at a mutually agreed rate that will not exceed (subject to certain exceptions) 1.0% of the volume-weighted average of the gross sales price per share of all of the borrowed shares of Sempra common stock sold through such forward seller. We intend to use a substantial portion of the net proceeds we receive from the issuance and sale by us of any shares of our common stock to or through the agents and any net proceeds we receive through the settlement of any forward sale agreements with the forward purchasers for working capital and other general corporate purposes, including to partly finance anticipated increases to our long-term capital plan and to repay outstanding commercial paper and potentially other indebtedness. November 2023 Forward Sale Agreements In November 2023, we completed the offering of 19,242,010 shares of our common stock, no par value, in a registered public offering at $70.00 per share ($68.845 per share after deducting underwriting discounts), 17,142,858 shares of which were pursuant to forward sale agreements. We discuss the common stock offering in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. As of November 6, 2024, a total of 17,142,858 shares of Sempra common stock from our November 2023 offering remain subject to future settlement under these forward sale agreements, which may be settled on one or more dates specified by us occurring no later than December 31, 2024, which is the final settlement date under the agreements. Although we expect to settle the forward sale agreements entirely by the physical delivery of shares of our common stock in exchange for cash proceeds, we may, subject to certain conditions, elect cash settlement or net share settlement for all or a portion of our obligations under the forward sale agreements. The forward sale agreements are also subject to acceleration by the counterparties to the agreements upon the occurrence of certain events. COMMON STOCK REPURCHASES In the nine months ended September 30, 2024 and 2023, we withheld 565,571 shares for $41 million and 411,447 shares for $32 million, respectively, of our common stock that would otherwise be issued to long-term incentive plan participants who do not elect otherwise upon the vesting of RSUs and exercise of stock options in an amount sufficient to satisfy minimum statutory tax withholding requirements. Such share withholding is considered a share repurchase for accounting purposes. NONCONTROLLING INTERESTS Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI. The following table summarizes net income attributable to Sempra and transfers (to) from NCI, which shows the effects of changes in Sempra’s ownership interest in its subsidiaries on Sempra’s shareholders’ equity. NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI (Dollars in millions) Three months ended Nine months ended September 30, 2023 Sempra: Net income attributable to Sempra $ 732 $ 2,327 Transfers (to) from NCI: Decrease in shareholders’ equity for sales of NCI (62) (44) Net transfers (to) from NCI (62) (44) Change from net income attributable to Sempra and transfers (to) from NCI $ 670 $ 2,283 SI Partners Contributions from NCI. In the three months and nine months ended September 30, 2023, KKR Pinnacle used $14 million and $200 million, respectively, of a credit from Sempra pursuant to the SI Partners limited partnership agreement, to fund its share of contributions to SI Partners. As a result, we recorded a $200 million increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $145 million, net of a tax benefit. SI Partners Subsidiaries Sale of NCI to KKR Denali. In September 2023, an indirect subsidiary of SI Partners completed the sale of a 60% interest in an SI Partners subsidiary (resulting in an indirect 42% NCI in the PA LNG Phase 1 project) to KKR Denali for aggregate cash consideration of $984 million, before post-closing adjustments recorded subsequently. As a result of this sale, we recorded a $1.1 billion increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $56 million, including $11 million in transaction costs and net of a $22 million tax benefit. The indirect subsidiary of SI Partners and KKR Denali have made capital contribution commitments to fund their respective equity share of the equity funding amount of anticipated development costs of the PA LNG Phase 1 project, except in certain budget overrun scenarios. Sale of NCI to ConocoPhillips Affiliate. In March 2023, an indirect subsidiary of SI Partners completed the sale of an indirect 30% interest in an SI Partners subsidiary (resulting in an indirect 30% NCI in the PA LNG Phase 1 project) to an affiliate of ConocoPhillips for aggregate cash consideration of $254 million. As a result of this sale, we recorded a $234 million increase in equity held by NCI and an increase in Sempra’s shareholders’ equity of $12 million, net of $3 million in transaction costs and $5 million in tax expense. The indirect subsidiary of SI Partners and the ConocoPhillips affiliate have made certain customary capital contribution commitments to fund their respective pro rata equity share of the total anticipated capital calls for the equity portion of the anticipated development costs of the PA LNG Phase 1 project. In addition, both SI Partners and ConocoPhillips have provided guarantees relating to their respective affiliate’s commitment to make its pro rata equity share of capital contributions to fund 110% of the development budget of the PA LNG Phase 1 project, in an aggregate amount of up to $9.0 billion. SI Partners’ guarantee covers 70% of this amount plus enforcement costs of its guarantee. As of September 30, 2024, an aggregate amount of $2.7 billion has been paid by SI Partners’ indirect subsidiary in satisfaction of its commitment to fund its portion of the development budget of the PA LNG Phase 1 project. 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Numerator: Earnings attributable to common shares $ 638 $ 721 $ 2,152 $ 2,293 Denominator: Weighted-average common shares outstanding for basic EPS (1) 633,752 630,036 633,342 629,963 Dilutive effect of common shares sold forward 2,312 — 1,375 — Dilutive effect of stock options and RSUs (2) 1,997 2,288 1,849 2,268 Weighted-average common shares outstanding for diluted EPS 638,061 632,324 636,566 632,231 EPS: Basic $ 1.01 $ 1.14 $ 3.40 $ 3.64 Diluted $ 1.00 $ 1.14 $ 3.38 $ 3.63 (1) Includes 615 and 716 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2024 and 2023, respectively, and 616 and 716 of such RSUs for the nine months ended September 30, 2024 and 2023, 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 nine months ended September 30, 2024 excludes 450,243 and 996,966 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and nine months ended September 30, 2023 excludes 624,242 and 470,804 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. The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we discuss above is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of our common stock shares is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS. Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Development Committee of Sempra’s board of directors granted 414,812 nonqualified stock options, 721,049 performance-based RSUs and 312,043 service-based RSUs in the nine months ended September 30, 2024, 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.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	9 Months Ended
	Sep. 30, 2024
Regulated Operations [Abstract]
SAN ONOFRE NUCLEAR GENERATING STATION	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES 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) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Fixed-price contracts and other derivatives $ 54 $ 215 $ 8 $ 14 $ 46 $ 201 Deferred income taxes recoverable in rates 1,526 1,142 780 626 660 430 Pension and PBOP plan obligations (255) (212) 51 48 (306) (260) Employee benefit costs 24 24 3 3 21 21 Removal obligations (3,261) (3,082) (2,650) (2,468) (611) (614) Environmental costs 148 139 115 105 33 34 Sunrise Powerlink fire mitigation 123 124 123 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (223) (233) (223) (233) — — Commodity – gas, including transportation (179) (259) 46 52 (225) (311) Safety and reliability 1,192 959 276 207 916 752 Public purpose programs (442) (273) (200) (144) (242) (129) Wildfire mitigation plan 811 685 811 685 — — Liability insurance premium 107 113 79 90 28 23 Other balancing accounts 306 373 (70) (152) 376 525 Other regulatory (liabilities) assets, net (2) (188) (10) (5) 49 (181) (58) Total $ (257) $ (295) $ (856) $ (994) $ 515 $ 614 (1) At September 30, 2024 and December 31, 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $2,090 and $1,913, respectively, for SDG&E was $979 and $950, respectively, and for SoCalGas was $1,111 and $963, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. 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. On October 18, 2024, the CPUC issued a proposed decision in the 2024 GRC for SDG&E’s and SoCalGas’ test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. The 2024 GRC proposed decision adopts a 2024 test year revenue requirement of $2,800 million for SDG&E’s combined operations ($2,198 million for its electric operations and $602 million for its natural gas operations), which is $207 million lower than the $3,007 million that SDG&E had requested in its updated application. The proposed 2024 combined revenue requirement, if adopted, represents an increase of $267 million (10.5%) compared to its authorized 2023 combined revenue requirement. The proposed post-test year revenue requirement, if adopted, would be annual increases of approximately 3.9% for 2025-2027 at SDG&E. The 2024 GRC proposed decision adopts a 2024 test year revenue requirement of $4,062 million for SoCalGas, which is $372 million lower than the $4,434 million that SoCalGas had requested in its May 2022 application. The proposed 2024 revenue requirement, if adopted, represents an increase of $523 million (14.8%) over its authorized 2023 revenue requirement. The proposed post-test year revenue requirement, if adopted, would be annual increases of approximately 3.9% for 2025-2027 at SoCalGas. Because a final decision for the 2024 GRC was not issued by September 30, 2024, SDG&E and SoCalGas recorded CPUC-authorized base revenues in the three months and nine months ended September 30, 2024 based on 2023 levels authorized under the 2019 GRC. The impact of the final decision, retroactive to January 1, 2024, as authorized by the CPUC, will be reflected in SDG&E’s and SoCalGas’ financial statements in the period in which the final decision is issued. We expect the CPUC to issue a final decision by the end of this year. 2024 GRC Track 2 In October 2023, SDG&E submitted a separate request to the CPUC in its 2024 GRC, known as a Track 2 request. This request seeks review and recovery of $1.5 billion of wildfire mitigation plan costs incurred from 2019 through 2022 that were in addition to amounts authorized in the 2019 GRC. SDG&E expects to receive a proposed reasonableness review decision for its Track 2 request in the first half of 2025. Revenues associated with the Track 2 request amounts described above have been recorded in a regulatory account. In February 2024, the CPUC approved an interim cost recovery mechanism that would permit SDG&E to recover in rates $194 million and $96 million of this regulatory account balance in 2024 and 2025, respectively. Such recovery of SDG&E’s wildfire mitigation plan regulatory account balance will be subject to refund, contingent on the reasonableness review decision for its Track 2 request. 2024 GRC Track 3 SDG&E expects to submit in the first half of 2025 an additional request to the CPUC in its 2024 GRC, known as a Track 3 request, for review and recovery of its 2023 wildfire mitigation plan costs. 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 was to remain in effect through December 31, 2025, subject to the CCM. AUTHORIZED COST OF CAPITAL FOR 2023 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. On September 30, 2023, the CCM was triggered for SDG&E and SoCalGas. In December 2023, the CPUC approved the following authorized rates of return effective January 1, 2024. AUTHORIZED COST OF CAPITAL FOR 2024 SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.34 % 1.96 % Long-Term Debt 45.60 % 4.54 % 2.07 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.65 5.54 Common Equity 52.00 10.50 5.46 100.00 % 7.67 % 100.00 % 7.67 % In October 2023, the CPUC issued a ruling to initiate a second phase of the 2023-2025 cost of capital proceeding to evaluate potential modifications to the CCM. In October 2024, the CPUC issued a final decision to modify the CCM. The final decision reduces the upward or downward adjustment to authorized ROE, if the CCM is triggered, to 20% of the change in the benchmark rate during the measurement period from the current 50%. The final decision adopts this change effective January 1, 2025, reducing both SDG&E’s and SoCalGas’ ROE by 42 bps to 10.23% and 10.08%, respectively, and allowing SDG&E and SoCalGas to update their respective costs of preferred equity and debt for 2025. SDG&E and SoCalGas intend to file advice letters in November 2024 to address the implementation, subject to approval, of the updated cost of capital. FERC RATE MATTERS SDG&E files separately with the FERC for its authorized transmission revenue requirement and ROE on FERC-regulated electric transmission operations and assets. SDG&E’s currently effective TO5 settlement provides for an 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). In May 2024, the CPUC and other parties filed a petition and complaint with the FERC seeking an order that directs SDG&E to remove the California ISO adder from its currently effective TO5 settlement and refund the California ISO adder retroactively from June 1, 2019. In June 2024, SDG&E exercised its right to terminate the TO5 settlement. Accordingly, in October 2024, SDG&E submitted its TO6 filing to the FERC to be effective January 1, 2025, subject to refund. SDG&E’s TO6 filing proposes, among other items, an increase to SDG&E’s currently authorized base ROE from 10.10% to 11.75% and continuation of the California ISO adder. SDG&E expects further proceedings on these two matters. 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 be completed around 2030. 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 2023, the CPUC granted SDG&E authorization to access NDT funds of up to $79 million for forecasted 2024 costs. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E 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 September 30, 2024 Short-term investments, primarily cash equivalents $ 18 $ — $ — $ 18 Equity securities 80 241 (2) 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 69 1 — 70 Municipal bonds (2) 290 3 (6) 287 Other securities (3) 233 4 (6) 231 Total debt securities 592 8 (12) 588 Receivables (payables), net (19) — — (19) Total $ 671 $ 249 $ (14) $ 906 December 31, 2023 Short-term investments, primarily cash equivalents $ 21 $ — $ — $ 21 Equity securities 89 225 (2) 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 50 2 (1) 51 Municipal bonds 280 3 (8) 275 Other securities 228 3 (11) 220 Total debt securities 558 8 (20) 546 Receivables (payables), net (7) — — (7) Total $ 661 $ 233 $ (22) $ 872 (1) Maturity dates are 2025 - 2055. (2) Maturity dates are 2024 - 2062. (3) Maturity dates are 2024 - 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Proceeds from sales $ 259 $ 143 $ 639 $ 437 Gross realized gains 17 12 41 20 Gross realized losses 2 3 7 9 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 $480 million at September 30, 2024 and is based on a cost study prepared in 2020, which the CPUC approved in August 2024. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $500 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $60 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $500 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed a negligible amount for retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2024
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 September 30, 2024, loss contingency accruals for legal matters that are probable and estimable were $53 million for Sempra, negligible for SDG&E and $28 million for SoCalGas. SDG&E City of San Diego Franchise Agreement In 2021, two lawsuits were filed in the California Superior Court challenging various aspects of the natural gas and electric franchise agreements granted by the City of San Diego to SDG&E. Both lawsuits ultimately sought to void the franchise agreements. In one of the cases, judgment was granted in favor of SDG&E and the City of San Diego, and the plaintiff in that case has appealed. We expect a ruling on the appeal in the first quarter of 2025. In the second case, the court ruled in favor of SDG&E and the City of San Diego, upholding all terms of the franchise agreements, except for the two-thirds City Council vote requirement for termination if the City decides to terminate under certain circumstances. Under the court’s ruling, the City can instead terminate on a majority vote, so long as it satisfies repayment provisions under the franchise agreements. Both sides have appealed the ruling. 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. 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) then 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 did not participate in the settlement (the Non-Settling Individual Plaintiffs) are able to continue to pursue their claims. As of November 1, 2024, there are approximately 520 plaintiffs, who are either new plaintiffs or Non-Settling Individual Plaintiffs. The new plaintiffs’ cases and Non-Settling Individual Plaintiffs’ cases are coordinated before a single court in the Los Angeles County Superior Court for pretrial management under a consolidated master complaint filed in November 2017, with one plaintiff’s case proceeding under a separate complaint. Both the consolidated master complaint and the separate complaint assert negligence, negligence per se, strict liability, negligent and intentional infliction of emotional distress and fraudulent concealment. The consolidated master complaint asserts additional causes of action for private and public nuisance (continuing and permanent), trespass, inverse condemnation, loss of consortium and wrongful death against SoCalGas and Sempra. The separate complaint asserts an additional cause of action for assault and battery. Both complaints seek compensatory and punitive damages for personal injuries, lost wages and/or lost profits, costs of future medical monitoring, and attorneys’ fees. The consolidated master complaint also seeks property damage and diminution in property value, injunctive relief and civil penalties. At September 30, 2024, $21 million is accrued in Other Current Liabilities and $1 million is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. These accruals do not include any amounts in excess of what has been reasonably estimated to resolve certain matters that we describe above, nor any amounts that may be necessary to resolve threatened litigation, other potential litigation or other costs. 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 and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. Aliso Canyon Natural Gas Storage Facility Regulatory Proceeding In February 2017, the CPUC opened proceeding 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. We expect a final decision by the end of this year. In August 2023, 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 68.6 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final decision within the SB 380 OII proceeding. At September 30, 2024, the Aliso Canyon natural gas storage facility had a net book value of $1.0 billion. 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, and natural gas reliability and electric generation could be jeopardized. Other Sempra 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 Facility and have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects. Land Disputes. Sempra Infrastructure has been engaged in a long-running land dispute with a claimant 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: ▪ The 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, as described above, had previously been issued in a ruling by the federal Agrarian Court and subsequently reversed by a federal court in Mexico. In April 2021, the proceeding in the Agrarian Court concluded with the court ordering that the administrative procedure be restarted. The administrative procedure at SEDATU may continue if SEDATU decides to reopen the matter. In addition, a plaintiff filed a claim in the federal Agrarian Court that 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. In August 2024, the Federal Collegiate Circuit Court ruled in favor of the ECA Regas Facility. The plaintiff has the option to file an appeal with the Mexican Supreme Court. 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 seeking revocation of 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 against the permits 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 to cancel the injunction but was not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiff and dismissed the lawsuit. The claimant appealed and the appellate court’s ruling is pending. ▪ In the second case, the initial request for a provisional injunction against the permits 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 construction activities did not violate the injunction. The claimants appealed this ruling but were not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiffs and dismissed the lawsuit. The claimants appealed and the appellate court’s ruling is pending. ▪ In the third case, a group of residents filed a complaint in June 2021 against various federal and state authorities alleging deficiencies in the public consultation process for the issuance of the permits. The request for an initial injunction was denied. The claimants appealed this ruling but were not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiffs and dismissed the lawsuit. The claimants appealed and the appellate court’s ruling is pending. Port Arthur LNG The PA LNG Phase 1 project holds two Clean Air Act, Prevention of Significant Deterioration permits issued by the TCEQ, which we refer to as the “2016 Permit” and the “2022 Permit.” The 2022 Permit also governs emissions for the proposed PA LNG Phase 2 project. In November 2023, a panel of the U.S. Court of Appeals for the Fifth Circuit issued a decision to vacate and remand the 2022 Permit to the TCEQ for additional explanation of the agency’s permit decision. In February 2024, the court withdrew its opinion and referred the case to the Supreme Court of Texas to resolve the question of the appropriate standard to be applied by the TCEQ. The 2022 Permit is effective during the Texas Supreme Court’s review. The 2016 Permit was not the subject of, and is unaffected by, the pending litigation of the 2022 Permit. Construction of the PA LNG Phase 1 project is proceeding uninterrupted under existing permits, and we do not currently anticipate the pending litigation to materially impact the PA LNG Phase 1 project cost, schedule or expected commercial operations at this stage. 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. The decree further purports to permit the CRE to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, if it considers them to have been obtained improperly. According to the decree, these amendments were to become effective in March 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. Numerous legal actions were taken against the decree, which resulted in Mexican courts issuing a suspension of the decree later in March 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. The super majority needed to find the amendment unconstitutional was not reached and the proceeding was therefore dismissed, leaving the amended Electricity Industry Law in place. However, the Court nevertheless found certain of the amendments, including the priority of dispatch for the CFE and other provisions that granted preference to the CFE over private companies, were invalid. In January 2024, the Second Chamber of the Mexican Supreme Court definitively resolved an amparo in a separate case brought by a third party and ruled that certain provisions of the amendments of the Electricity Industry Law are unconstitutional, including the priority of dispatch for the CFE and other provisions that granted preference to the CFE over private companies. The Court also dismissed an amparo relating to the provision of the decree applicable to self-supply permits granted under the former electricity law, and established that its decision applies generally over all participants. Sempra Infrastructure filed three lawsuits challenging the amendments to the Electricity Industry Law, including one concerning the provision permitting revocation of self-supply permits deemed improperly obtained. In each of them, Sempra Infrastructure obtained a favorable judgment in the lower court, all of which were challenged by the CRE. Following the criteria established by the Mexican Supreme Court, in July 2024, the Second Collegiate Court reversed the lower court’s decision and definitively dismissed one of the lawsuits filed by Sempra Infrastructure regarding the provision permitting revocation of self-supply permits. Consequently, the CRE may be required to seek to revoke such self-supply permits, under a legal standard that is ambiguous and not well defined under the law. Sempra Infrastructure supplies power pursuant to self-supply permits, and would be permitted to file amparos challenging the constitutionality of any such action. If such self-supply permits are revoked, it may result in increased costs for Sempra Infrastructure and for its power consumers, adversely affect our ability to develop new projects, result in decreased revenues and cash flows, and negatively impact our ability to recover the carrying values of our investments in Mexico, any of which could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects. Final resolution regarding the two remaining lawsuits is still pending. RBS Sempra Commodities – Resolved Sempra holds an equity method investment in RBS Sempra Commodities LLP, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against The Royal Bank of Scotland plc (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 Sempra Energy Europe, a subsidiary of RBS Sempra Commodities LLP. The claim alleged 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 were liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. In January 2024, the parties settled the Liquidating Companies’ claim against the Defendants to fully resolve the matter; our share of such settlement was approximately £7.9 million (approximately $10 million in U.S. dollars at December 31, 2023). For the year ended December 31, 2023, we recorded $40 million in equity earnings from our investment in RBS Sempra Commodities LLP to reduce our estimate of our obligations to settle these VAT matters and related legal costs based on the settlement reached with the Liquidating Companies in January 2024. 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 November 1, 2024, one lawsuit is 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, aircraft, 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 tolling agreement that commenced in September 2024 and expires in August 2036. SDG&E recorded an operating lease right-of-use asset and operating lease liability of $202 million. Future minimum lease payments are $4 million in 2024, $23 million in each of 2025 through 2028 and $182 million thereafter. Leases That Have Not Yet Commenced SDG&E has entered into six PPAs, of which SDG&E expects two will commence in 2024, two will commence in 2025 and two will commence in 2026. SDG&E expects the future minimum lease payments to be $5 million in 2024, $41 million in 2025, $67 million in 2026, $68 million in both 2027 and 2028 and $777 million thereafter (through expiration in 2041). SoCalGas has entered into a lease agreement for a new headquarters office space in Los Angeles that it expects will commence in 2026. In September 2024, SoCalGas prepaid $1 million and expects the future minimum lease payments to be $8 million in 2028 and $143 million thereafter (through expiration in 2041). Sempra Infrastructure has entered into a lease agreement for tugboat services for the PA LNG Phase 1 project that it expects will commence in 2027. Sempra Infrastructure expects the future minimum lease payments to be $10 million in 2027, $12 million in 2028 and $210 million thereafter (through expiration in 2047, exclusive of certain renewal options) and total future minimum fixed payments for operation and maintenance services to be $184 million. 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 (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra – Sales-type leases: Interest income $ 1 $ 2 $ 4 $ 5 Total revenues from sales-type leases (1) $ 1 $ 2 $ 4 $ 5 Sempra – Operating leases: Fixed lease payments $ 83 $ 78 $ 259 $ 234 Variable lease payments 9 10 29 26 Total revenues from operating leases (1) $ 92 $ 88 $ 288 $ 260 Depreciation expense $ 17 $ 15 $ 53 $ 45 (1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations. CONTRACTUAL COMMITMENTS We discuss below significant changes in the first nine months of 2024 to contractual commitments discussed in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. Natural Gas Contracts SoCalGas’ natural gas contracts and transportation commitments have increased by approximately $340 million since December 31, 2023, primarily from entering into new natural gas contracts in the first nine months of 2024. At September 30, 2024, we expect future payments to decrease by $7 million in 2024, and increase by $36 million in 2025, $111 million in 2026, $119 million in 2027, and $81 million in 2028 compared to December 31, 2023. Sempra Infrastructure’s natural gas contracts and transportation commitments have increased by approximately $474 million since December 31, 2023, primarily from entering into new natural gas contracts in the first nine months of 2024. We expect future payments to decrease by $17 million in 2024, and increase by $4 million in 2025, $76 million in 2026, $98 million in each of 2027 and 2028, and $215 million thereafter (through expiration in 2059) compared to December 31, 2023. 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 2024 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 September 30, 2024, we expect the commitment amount to decrease by $321 million in 2024, $76 million in 2025, $51 million in 2026, $37 million in 2027, $45 million in 2028 and $30 million thereafter (through expiration in 2029) compared to December 31, 2023, reflecting changes in estimated forward prices since December 31, 2023 and actual transactions for the first nine months of 2024. These LNG commitment amounts are based on the assumption that all LNG cargoes under the agreement are delivered, less those already confirmed to be diverted as of September 30, 2024. 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 $51 million for Sempra, $18 million for SDG&E and $20 million for SoCalGas at September 30, 2024.

SEMPRA - SEGMENT INFORMATION

SEMPRA - SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2024
Segment Reporting [Abstract]
SEMPRA - SEGMENT INFORMATION	SEMPRA – SEGMENT INFORMATION Sempra has three separately managed reportable segments, as follows: ▪ Sempra California provides natural gas and electric service to Southern California and part of central California through Sempra’s wholly owned subsidiaries, SDG&E and SoCalGas. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪ Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns a 70% interest in SI Partners. 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 Balance Sheets, Condensed Consolidated Statements of Cash Flows and Condensed Consolidated Statements of Operations. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations. SEGMENT INFORMATION (Dollars in millions) September 30, December 31, ASSETS Sempra California $ 56,220 $ 53,430 Sempra Texas Utilities 15,292 14,392 Sempra Infrastructure 21,828 19,430 All other 1,434 967 Intersegment receivables (1,026) (1,038) Total $ 93,748 $ 87,181 EQUITY METHOD AND OTHER INVESTMENTS Sempra Texas Utilities $ 15,280 $ 14,380 Sempra Infrastructure 2,291 2,129 All other 1 1 Total $ 17,572 $ 16,510 Nine months ended September 30, 2024 2023 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT Sempra California $ 3,329 $ 3,344 Sempra Infrastructure 2,433 2,725 All other 3 5 Total $ 5,765 $ 6,074 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 REVENUES Sempra California $ 2,256 $ 2,725 $ 8,022 $ 10,840 Sempra Infrastructure 538 629 1,466 2,485 Adjustments and eliminations (1) 1 (1) (1) Intersegment revenues (1) (17) (21) (60) (95) Total $ 2,776 $ 3,334 $ 9,427 $ 13,229 DEPRECIATION AND AMORTIZATION Sempra California $ 536 $ 491 $ 1,585 $ 1,435 Sempra Infrastructure 76 71 221 210 All other 2 1 5 6 Total $ 614 $ 563 $ 1,811 $ 1,651 INTEREST INCOME Sempra California $ 4 $ 9 $ 12 $ 19 Sempra Infrastructure 7 4 19 25 All other 6 7 17 17 Intercompany eliminations — (1) (1) (1) Total $ 17 $ 19 $ 47 $ 60 INTEREST EXPENSE Sempra California $ 213 $ 196 $ 627 $ 577 Sempra Texas Utilities 1 — 1 — Sempra Infrastructure — 7 — 127 All other 116 109 319 292 Intercompany eliminations (2) — (3) (1) Total $ 328 $ 312 $ 944 $ 995 INCOME TAX (BENEFIT) EXPENSE Sempra California $ (37) $ (20) $ 90 $ 64 Sempra Texas Utilities 1 — 1 — Sempra Infrastructure (43) 24 (67) 555 All other (26) (56) (87) (120) Total $ (105) $ (52) $ (63) $ 499 EQUITY EARNINGS Equity earnings, before income tax: Sempra Texas Utilities $ 2 $ 2 $ 6 $ 5 Sempra Infrastructure 130 131 420 413 132 133 426 418 Equity earnings, net of income tax: Sempra Texas Utilities 261 305 646 548 Sempra Infrastructure 61 41 163 120 322 346 809 668 Total $ 454 $ 479 $ 1,235 $ 1,086 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES Sempra California $ 247 $ 290 $ 1,145 $ 1,247 Sempra Texas Utilities 261 305 646 548 Sempra Infrastructure 230 223 652 746 All other (100) (97) (291) (248) Total $ 638 $ 721 $ 2,152 $ 2,293 (1) Revenues for reportable segments include intersegment revenues of $6 and $11 for the three months ended September 30, 2024 and $16 and $44 for the nine months ended September 30, 2024; $5 and $16 for the three months ended September 30, 2023 and $14 and $81 for the nine months ended September 30, 2023 for Sempra California and Sempra Infrastructure, respectively.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Pay vs Performance Disclosure
Net income attributable to Sempra	$ 649	$ 732	$ 2,186	$ 2,327

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended	9 Months Ended
	Sep. 30, 2024 shares	Sep. 30, 2024 shares
Trading Arrangements, by Individual
Material Terms of Trading Arrangement		RULE 10B5-1 TRADING ARRANGEMENT (Three months ended September 30, 2024) Name and title of the director or officer Date on which the director or officer adopted or terminated the trading arrangement Duration of the trading arrangement Aggregate number of securities to be purchased or sold pursuant to the trading arrangement Sempra: Justin C. Bird, Executive Vice President September 18, 2024 From April 1, 2025 until all shares are sold or the trading arrangement is otherwise terminated ▪ 35% of the shares of Sempra common stock subject to 4,579 performance-based RSUs vesting in January and February of 2025 (1) ▪ 35% of the shares of Sempra common stock subject to 4,756 performance-based RSUs vesting in January and February of 2026 (1) in each case, less shares to which Mr. Bird would otherwise be entitled that are withheld to satisfy minimum statutory tax withholding requirements Jeffrey W. Martin, Chairman, Chief Executive Officer and President August 12, 2024 From January 30, 2025 until all shares are sold or the trading arrangement is otherwise terminated All shares of Sempra common stock subject to 104,540 performance-based RSUs vesting in January and February of 2025 (1) , less shares to which Mr. Martin would otherwise be entitled that are withheld to satisfy minimum statutory tax withholding requirements (1) Shares subject to the performance-based RSUs scheduled to vest in January and February of 2025 and 2026 generally will vest, in whole or in part, or be forfeited in early 2025 or early 2026, as applicable, based on our total shareholder return for the three-year performance period ending on January 2, 2025 and January 2, 2026, as applicable, and EPS growth (as adjusted for long-term incentive plan purposes) for the three-year performance period ending on December 31, 2024 and December 31, 2025, as applicable. The number of shares that will vest may range from 0% to 200% of the target number of shares (plus dividend equivalents) and cannot be ascertained until the performance period has ended and the Compensation and Talent Development Committee of Sempra’s board of directors has certified the results.
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false
Justin C Bird [Member]
Trading Arrangements, by Individual
Name	Justin C. Bird
Title	Executive Vice President
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	September 18, 2024
Jeffrey W Martin [Member]
Trading Arrangements, by Individual
Name	Jeffrey W. Martin
Title	Chairman, Chief Executive Officer and President
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	August 12, 2024
Sempra Common Stock Subject To Performance-Based RSUs Vesting In 2025 [Member] | Justin C Bird [Member]
Trading Arrangements, by Individual
Aggregate Available	4,579	4,579
Sempra Common Stock Subject To Performance-Based RSUs Vesting In 2025 [Member] | Jeffrey W Martin [Member]
Trading Arrangements, by Individual
Aggregate Available	104,540	104,540
Sempra Common Stock Subject To Performance-Based RSUs Vesting In 2026 [Member] | Justin C Bird [Member]
Trading Arrangements, by Individual
Aggregate Available	4,756	4,756

GENERAL INFORMATION AND OTHER_2

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	9 Months Ended
	Sep. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities, which invest in, develop and operate energy infrastructure in North America, and provide electric and gas services to customers. Sempra has three separate reportable segments, which we describe in Note 12. In the fourth quarter of 2023, Sempra realigned its reportable segments to reflect changes in how the CODM oversees our three platforms: Sempra California, Sempra Texas Utilities and Sempra Infrastructure. Our former SDG&E and SoCalGas reportable segments were combined into one operating and reportable segment, Sempra California, which is consistent with how the CODM assesses performance due to the similarities of their operations, including geographic location and regulatory framework in California. Sempra’s historical segment disclosures have been restated to conform with the current presentation, so that all discussions reflect the revised segment information of its three reportable segments. 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. SDG&E is a regulated public utility that provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. SDG&E has one reportable segment. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra. SoCalGas is a regulated public natural gas distribution utility, serving customers throughout most of Southern California and part of central California. SoCalGas has one reportable segment.
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 the condensed consolidated financial statements of each Registrant. 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 September 30, 2024 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, 2023 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2023 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. Our Sempra Infrastructure segment includes the operating companies of our subsidiary, SI Partners, as well as certain holding companies and risk management activity. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP.
Variable Interest Entity	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.
Credit Losses	CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in 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.
Interim Period Effective Tax Rate	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	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, in 2023, the scope of projects eligible for ITCs was expanded to include standalone energy storage projects, which are transferable under the IRA. The IRA also provided an election through 2024 that permits ITCs 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. In April 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 nine months ended September 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. Sempra elected this change in tax accounting method in its consolidated 2023 income tax return filing, and Sempra, SDG&E and SoCalGas have applied this methodology in the calculation of their 2024 forecasted ETRs. Sempra, SDG&E, and SoCalGas record regulatory liabilities for benefits that will be flowed through to customers in the future.
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 March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps maturing in 2048, which were designated as cash flow hedges. On September 30, 2024, Port Arthur LNG voluntarily de-designated those interest rate swaps that begin hedging interest payments in March 2026 to provide for future financing flexibility. At the time of de-designation, $40 million of deferred gains related to the de-designated notional amount were included in AOCI, which will remain in AOCI until the hedged interest payments impact earnings or such hedged interest payments become probable of not occurring. In October 2024, Port Arthur LNG received a cash settlement of $46 million, net of transaction costs, for the termination of $1.0 billion of the notional amount of both the designated and de-designated interest rate swaps, with the associated deferred gains remaining in AOCI. 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. In May 2024, Oncor entered into cross-currency swaps designated as fair value hedges intended to offset foreign currency exchange rate risk related to its Euro-denominated debt. 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	We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2023. 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 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 – Other Sempra.” 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. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Other Sempra Fair Value of Financial Instruments
Earnings Per Common Share	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.
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	Sempra has three separately managed reportable segments, as follows: ▪ Sempra California provides natural gas and electric service to Southern California and part of central California through Sempra’s wholly owned subsidiaries, SDG&E and SoCalGas. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪ Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns a 70% interest in SI Partners. 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)	9 Months Ended
	Sep. 30, 2024
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. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) September 30, December 31, Sempra: Cash and cash equivalents $ 560 $ 236 Restricted cash, current 22 49 Restricted cash, noncurrent 108 104 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 690 $ 389
Accounts Receivable, Allowance for Credit Loss	Changes in allowances for credit losses for trade receivables and other receivables are as follows: CHANGES IN ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) 2024 2023 Sempra: Allowances for credit losses at January 1 $ 533 $ 181 Provisions for expected credit losses 149 374 Write-offs (169) (74) Allowances for credit losses at September 30 $ 513 $ 481 SDG&E: Allowances for credit losses at January 1 $ 144 $ 78 Provisions for expected credit losses 46 96 Write-offs (63) (34) Allowances for credit losses at September 30 $ 127 $ 140 SoCalGas: Allowances for credit losses at January 1 $ 331 $ 98 Provisions for expected credit losses 70 276 Write-offs (107) (40) Allowances for credit losses at September 30 $ 294 $ 334 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) September 30, December 31, 2024 2023 Sempra: Accounts receivable – trade, net $ 441 $ 480 Accounts receivable – other, net 57 52 Other long-term assets 15 1 Total allowances for credit losses $ 513 $ 533 SDG&E: Accounts receivable – trade, net $ 94 $ 116 Accounts receivable – other, net 26 27 Other long-term assets 7 1 Total allowances for credit losses $ 127 $ 144 SoCalGas: Accounts receivable – trade, net $ 255 $ 306 Accounts receivable – other, net 31 25 Other long-term assets 8 — Total allowances for credit losses $ 294 $ 331
Schedule of Related Party Transactions	We summarize amounts due from and to unconsolidated affiliates at the Registrants in the following table. AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) September 30, December 31, Sempra: Tax sharing arrangement with Oncor Holdings $ 8 $ 25 Various affiliates 6 6 Total due from unconsolidated affiliates – current $ 14 $ 31 TAG Pipelines – 5.5% Note due January 9, 2024 (1) $ — $ (5) Total due to unconsolidated affiliates – current $ — $ (5) TAG Pipelines (1) : 5.5% Note due January 14, 2025 $ — $ (24) 5.5% Note due July 16, 2025 — (23) 5.5% Note due January 14, 2026 (8) (20) 5.5% Note due July 14, 2026 (12) (11) 5.5% Note due January 19, 2027 (15) (14) 5.5% Note due July 21, 2027 (18) (17) 5.5% Note due January 19, 2028 (47) — 5.5% Note due July 18, 2028 (41) — TAG Norte – 5.74% Note due December 17, 2029 (1) (206) (198) Total due to unconsolidated affiliates – noncurrent $ (347) $ (307) SDG&E: SoCalGas $ 8 $ — Total due from unconsolidated affiliates – current $ 8 $ — Sempra $ (40) $ (44) SoCalGas — (21) Various affiliates (8) (8) Total due to unconsolidated affiliates – current $ (48) $ (73) Income taxes due from Sempra (2) $ 251 $ 246 SoCalGas: SDG&E $ — $ 21 Various affiliates 2 1 Total due from unconsolidated affiliates – current $ 2 $ 22 Sempra $ (35) $ (38) SDG&E (8) — Total due to unconsolidated affiliates – current $ (43) $ (38) Income taxes due from Sempra (2) $ 9 $ 6 (1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding and VAT payable to the Mexican government. (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. We summarize income statement information from unconsolidated affiliates in the following table. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Revenues $ 11 $ 10 $ 31 $ 34 Interest expense 5 3 12 11 SDG&E: Revenues $ 6 $ 5 $ 17 $ 15 Cost of sales 36 25 111 82 SoCalGas: Revenues $ 43 $ 29 $ 124 $ 91 Cost of sales (1) (2) 2 (5) 37 (1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.
Schedule of Inventory, Current	The components of inventories are as follows: INVENTORY BALANCES (Dollars in millions) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Natural gas $ 166 $ 174 $ 1 $ 1 $ 153 $ 155 LNG 13 9 — — — — Materials and supplies 340 299 181 152 130 122 Total $ 519 $ 482 $ 182 $ 153 $ 283 $ 277
Schedule of Capitalization	The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra $ 166 $ 128 $ 466 $ 311 SDG&E 27 28 80 90 SoCalGas 25 20 75 55
Schedule of Accumulated Other Comprehensive Income (Loss)	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 September 30, 2024 and 2023 Sempra: Balance at June 30, 2024 $ (49) $ 35 $ (107) $ (121) OCI before reclassifications (12) (49) — (61) Amounts reclassified from AOCI — (5) 2 (3) Net OCI (12) (54) 2 (64) Balance at September 30, 2024 $ (61) $ (19) $ (105) $ (185) Balance at June 30, 2023 $ (38) $ 14 $ (97) $ (121) OCI before reclassifications (5) 116 — 111 Amounts reclassified from AOCI (2) — (51) 1 (50) Net OCI (2) (5) 65 1 61 Balance at September 30, 2023 $ (43) $ 79 $ (96) $ (60) SDG&E: Balance at June 30, 2024 and September 30, 2024 $ (8) $ (8) Balance at June 30, 2023 and September 30, 2023 $ (7) $ (7) SoCalGas: Balance at June 30, 2024 and September 30, 2024 $ (10) $ (11) $ (21) Balance at June 30, 2023 and September 30, 2023 $ (11) $ (11) $ (22) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $(46) of financial instruments associated with sale of NCI to KKR Denali in 2023, which we discuss in Note 9 in “Noncontrolling Interests – SI Partners Subsidiaries.” 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 Nine months ended September 30, 2024 and 2023 Sempra: Balance at December 31, 2023 $ (36) $ 3 $ (117) $ (150) OCI before reclassifications (25) (1) 1 (25) Amounts reclassified from AOCI — (21) 11 (10) Net OCI (25) (22) 12 (35) Balance at September 30, 2024 $ (61) $ (19) $ (105) $ (185) Balance at December 31, 2022 $ (59) $ 10 $ (86) $ (135) OCI before reclassifications 16 129 (13) 132 Amounts reclassified from AOCI (2) — (60) 3 (57) Net OCI (2) 16 69 (10) 75 Balance at September 30, 2023 $ (43) $ 79 $ (96) $ (60) SDG&E: Balance at December 31, 2023 and September 30, 2024 $ (8) $ (8) Balance at December 31, 2022 and September 30, 2023 $ (7) $ (7) SoCalGas: Balance at December 31, 2023 $ (11) $ (12) $ (23) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at September 30, 2024 $ (10) $ (11) $ (21) Balance at December 31, 2022 $ (12) $ (12) $ (24) Amounts reclassified from AOCI 1 1 2 Net OCI 1 1 2 Balance at September 30, 2023 $ (11) $ (11) $ (22) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $(46) of financial instruments associated with sale of NCI to KKR Denali in 2023, which we discuss in Note 9 in “Noncontrolling Interests – SI Partners Subsidiaries.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).
Reclassifications out of AOCI	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about AOCI components Amounts reclassified Affected line item on Condensed Three months ended September 30, 2024 2023 Sempra: Financial instruments: Interest rate instruments $ (3) $ 1 Interest expense Interest rate instruments (5) (12) Equity earnings (1) Foreign exchange instruments (1) (1) Other income, net Foreign exchange instruments (1) (1) Equity earnings (1) Total, before income tax (10) (13) 3 2 Income tax benefit (expense) Total, net of income tax (7) (11) 2 6 Earnings attributable to noncontrolling interests Total, net of income tax and after NCI $ (5) $ (5) Pension and PBOP (2) : Amortization of actuarial loss $ 2 $ 1 Other income, net Amortization of prior service cost 1 1 Other income, net Total, before income tax 3 2 (1) (1) Income tax benefit (expense) Total, net of income tax $ 2 $ 1 Total reclassifications for the period, net of income tax and after NCI $ (3) $ (4) (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED) (Dollars in millions) Details about AOCI components Amounts reclassified Affected line item on Condensed Nine months ended September 30, 2024 2023 Sempra: Financial instruments: Interest rate instruments $ (9) $ 1 Interest expense Interest rate instruments (20) (33) Equity earnings (1) Foreign exchange instruments (5) — Revenues: Energy-related businesses (2) 1 Other income, net Foreign exchange instruments (5) 1 Equity earnings (1) Interest rate and foreign exchange instruments — (1) Interest expense — (6) Other income, net Total, before income tax (41) (37) 9 5 Income tax benefit (expense) Total, net of income tax (32) (32) 11 18 Earnings attributable to noncontrolling interests Total, net of income tax and after NCI $ (21) $ (14) Pension and PBOP (2) : Amortization of actuarial loss $ 5 $ 2 Other income, net Amortization of prior service cost 2 2 Other income, net Settlement charges 9 — Other income, net Total, before income tax 16 4 (5) (1) Income tax benefit (expense) Total, net of income tax $ 11 $ 3 Total reclassifications for the period, net of income tax and after NCI $ (10) $ (11) SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 Interest expense Pension and PBOP (2) : Amortization of prior service cost $ 1 $ 1 Other income (expense), net Total reclassifications for the period, net of income tax $ 2 $ 2 (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax. (2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below).
Schedule of Net Benefit Costs	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 Other Income, Net. NET PERIODIC BENEFIT COST (Dollars in millions) Pension PBOP Three months ended September 30, 2024 2023 2024 2023 Sempra: Service cost $ 34 $ 25 $ 4 $ 3 Interest cost 41 39 9 9 Expected return on assets (40) (42) (19) (17) Amortization of: Prior service cost (credit) 1 2 (1) (1) Actuarial loss (gain) 4 3 (4) (5) Net periodic benefit cost (credit) 40 27 (11) (11) Regulatory adjustments 20 30 10 10 Total expense (income) recognized $ 60 $ 57 $ (1) $ (1) SDG&E: Service cost $ 10 $ 8 $ — $ 1 Interest cost 10 10 3 2 Expected return on assets (10) (9) (3) (2) Amortization of: Actuarial loss 3 2 — — Net periodic benefit cost 13 11 — 1 Regulatory adjustments — 3 — (1) Total expense recognized $ 13 $ 14 $ — $ — SoCalGas: Service cost $ 21 $ 15 $ 3 $ 2 Interest cost 26 24 7 7 Expected return on assets (29) (29) (15) (14) Amortization of: Prior service cost (credit) 1 1 (1) (1) Actuarial loss (gain) 1 1 (4) (5) Net periodic benefit cost (credit) 20 12 (10) (11) Regulatory adjustments 20 27 10 11 Total expense recognized $ 40 $ 39 $ — $ — NET PERIODIC BENEFIT COST (CONTINUED) (Dollars in millions) Pension PBOP Nine months ended September 30, 2024 2023 2024 2023 Sempra: Service cost $ 99 $ 82 $ 11 $ 10 Interest cost 124 118 27 28 Expected return on assets (131) (127) (53) (52) Amortization of: Prior service cost (credit) 4 4 (2) (2) Actuarial loss (gain) 10 7 (12) (17) Settlement charges 9 — — — Net periodic benefit cost (credit) 115 84 (29) (33) Regulatory adjustments 21 88 28 32 Total expense (income) recognized $ 136 $ 172 $ (1) $ (1) SDG&E: Service cost $ 29 $ 24 $ 2 $ 2 Interest cost 32 30 6 6 Expected return on assets (33) (29) (7) (6) Amortization of: Actuarial loss (gain) 6 4 (1) (1) Net periodic benefit cost 34 29 — 1 Regulatory adjustments (7) 11 — (1) Total expense recognized $ 27 $ 40 $ — $ — SoCalGas: Service cost $ 59 $ 49 $ 8 $ 7 Interest cost 78 75 21 21 Expected return on assets (90) (89) (45) (44) Amortization of: Prior service cost (credit) 3 3 (2) (2) Actuarial loss (gain) 1 1 (10) (15) Net periodic benefit cost (credit) 51 39 (28) (33) Regulatory adjustments 28 77 28 33 Total expense recognized $ 79 $ 116 $ — $ —
Schedule of Other Nonoperating Income (Expense)	Other Income, Net, consists of the following: OTHER INCOME (EXPENSE), NET (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Allowance for equity funds used during construction $ 39 $ 35 $ 114 $ 105 Investment gains (losses), net (1) 29 (19) 48 (2) Gains on interest rate and foreign exchange instruments, net 1 1 2 5 Foreign currency transaction (losses) gains, net (5) (3) (6) 1 Non-service components of net periodic benefit cost (21) (28) (25) (79) Interest on regulatory balancing accounts, net 26 19 68 56 Sundry, net (4) (2) (7) (11) Total $ 65 $ 3 $ 194 $ 75 SDG&E: Allowance for equity funds used during construction $ 21 $ 21 $ 60 $ 67 Non-service components of net periodic benefit cost (3) (5) 4 (14) Interest on regulatory balancing accounts, net 12 10 30 31 Sundry, net — (1) (8) (9) Total $ 30 $ 25 $ 86 $ 75 SoCalGas: Allowance for equity funds used during construction $ 18 $ 14 $ 54 $ 38 Non-service components of net periodic benefit cost (16) (22) (12) (60) Interest on regulatory balancing accounts, net 14 9 38 25 Sundry, net (3) (3) (7) (12) Total $ 13 $ (2) $ 73 $ (9) (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.
Schedule of Effective Income Tax Rate Reconciliation	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Income tax (benefit) expense $ (105) $ (52) $ (63) $ 499 Income before income taxes and equity earnings $ 200 $ 323 $ 1,213 $ 2,175 Equity earnings, before income tax (1) 132 133 426 418 Pretax income $ 332 $ 456 $ 1,639 $ 2,593 Effective income tax rate (32) % (11) % (4) % 19 % SDG&E: Income tax expense (benefit) $ 15 $ (15) $ 89 $ (4) Income before income taxes $ 276 $ 259 $ 759 $ 712 Effective income tax rate 5 % (6) % 12 % (1) % SoCalGas: Income tax (benefit) expense $ (52) $ (5) $ 1 $ 68 (Loss) income before income taxes $ (66) $ 11 $ 477 $ 600 Effective income tax rate 79 % (45) % — % 11 % (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)	9 Months Ended
	Sep. 30, 2024
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregation of Revenue	The following tables disaggregate our revenues from contracts with customers by major service line and market. We also provide a reconciliation to total revenues by segment for Sempra. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) Sempra Sempra California Sempra Infrastructure Consolidating adjustments and Parent Sempra Three months ended September 30, 2024 By major service line: Utilities $ 2,394 $ 15 $ (7) $ 2,402 Energy-related businesses — 179 (12) 167 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 By market: Gas $ 1,237 $ 83 $ (6) $ 1,314 Electric 1,157 111 (13) 1,255 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 Revenues from contracts with customers $ 2,394 $ 194 $ (19) $ 2,569 Utilities regulatory revenues (138) — — (138) Other revenues — 344 1 345 Total revenues $ 2,256 $ 538 $ (18) $ 2,776 Three months ended September 30, 2023 By major service line: Utilities $ 2,528 $ 18 $ (5) $ 2,541 Energy-related businesses — 369 (16) 353 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 By market: Gas $ 1,275 $ 234 $ (3) $ 1,506 Electric 1,253 153 (18) 1,388 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 Revenues from contracts with customers $ 2,528 $ 387 $ (21) $ 2,894 Utilities regulatory revenues 197 — — 197 Other revenues — 242 1 243 Total revenues $ 2,725 $ 629 $ (20) $ 3,334 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) Sempra Sempra California Sempra Infrastructure Consolidating adjustments and Parent Sempra Nine months ended September 30, 2024 By major service line: Utilities $ 8,129 $ 63 $ (18) $ 8,174 Energy-related businesses — 625 (49) 576 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 By market: Gas $ 4,961 $ 356 $ (15) $ 5,302 Electric 3,168 332 (52) 3,448 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 Revenues from contracts with customers $ 8,129 $ 688 $ (67) $ 8,750 Utilities regulatory revenues (107) — — (107) Other revenues — 778 6 784 Total revenues $ 8,022 $ 1,466 $ (61) $ 9,427 Nine months ended September 30, 2023 By major service line: Utilities $ 10,764 $ 67 $ (16) $ 10,815 Energy-related businesses — 916 (56) 860 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 By market: Gas $ 7,158 $ 605 $ (13) $ 7,750 Electric 3,606 378 (59) 3,925 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 Revenues from contracts with customers $ 10,764 $ 983 $ (72) $ 11,675 Utilities regulatory revenues 76 — — 76 Other revenues — 1,502 (24) 1,478 Total revenues $ 10,840 $ 2,485 $ (96) $ 13,229 DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Three months ended September 30, 2024 2023 2024 2023 By major service line: Revenues from contracts with customers – Utilities $ 1,327 $ 1,438 $ 1,110 $ 1,120 By market: Gas $ 167 $ 182 $ 1,110 $ 1,120 Electric 1,160 1,256 — — Revenues from contracts with customers $ 1,327 $ 1,438 $ 1,110 $ 1,120 Revenues from contracts with customers $ 1,327 $ 1,438 $ 1,110 $ 1,120 Utilities regulatory revenues (84) 4 (56) 193 Total revenues $ 1,243 $ 1,442 $ 1,054 $ 1,313 Nine months ended September 30, 2024 2023 2024 2023 By major service line: Revenues from contracts with customers – Utilities $ 3,836 $ 4,603 $ 4,416 $ 6,252 By market: Gas $ 658 $ 988 $ 4,416 $ 6,252 Electric 3,178 3,615 — — Revenues from contracts with customers $ 3,836 $ 4,603 $ 4,416 $ 6,252 Revenues from contracts with customers $ 3,836 $ 4,603 $ 4,416 $ 6,252 Utilities regulatory revenues 141 (246) (248) 322 Total revenues $ 3,977 $ 4,357 $ 4,168 $ 6,574
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at September 30, 2024, 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 for contracts greater than one year at September 30, 2024. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra SDG&E 2024 (excluding first nine months of 2024) $ 90 $ — 2025 321 4 2026 321 4 2027 321 4 2028 253 4 Thereafter 2,313 56 Total revenues to be recognized $ 3,619 $ 72 (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 nine months ended September 30, 2024 or 2023. Sempra Infrastructure recorded a contract liability for funds held as collateral in lieu of a customer’s letters of credit primarily associated with its LNG storage and regasification agreement. CONTRACT LIABILITIES (Dollars in millions) 2024 2023 Sempra: Contract liabilities at January 1 $ (198) $ (252) Revenue from performance obligations satisfied during reporting period 5 9 Payments received in advance (3) (21) Contract liabilities at September 30 (1) $ (196) $ (264) SDG&E: Contract liabilities at January 1 $ (75) $ (79) Revenue from performance obligations satisfied during reporting period 3 3 Contract liabilities at September 30 (2) $ (72) $ (76) (1) Balances at September 30, 2024 include $4 in Other Current Liabilities and $192 in Deferred Credits and Other. (2) Balances at September 30, 2024 include $3 in Other Current Liabilities and $69 in Deferred Credits and Other.
Schedule of Contract Accounts Receivable	The table below shows receivable balances, net of allowances for credit losses, associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) September 30, 2024 December 31, 2023 Sempra: Accounts receivable – trade, net (1) $ 1,490 $ 1,951 Accounts receivable – other, net 20 15 Due from unconsolidated affiliates – current (2) 4 4 Other long-term assets (3) 20 — Total $ 1,534 $ 1,970 SDG&E: Accounts receivable – trade, net (1) $ 867 $ 870 Accounts receivable – other, net 19 13 Due from unconsolidated affiliates – current (2) 7 6 Other long-term assets (3) 6 — Total $ 899 $ 889 SoCalGas: Accounts receivable – trade, net $ 557 $ 985 Accounts receivable – other, net 1 2 Other long-term assets (3) 14 — Total $ 572 $ 987 (1) At September 30, 2024 and December 31, 2023, includes $223 and $148, respectively, of receivables due from customers that were billed on behalf of Community Choice Aggregators, 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 January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	9 Months Ended
	Sep. 30, 2024
Regulated Operations [Abstract]
Schedule of Regulatory Assets	REGULATORY ASSETS (LIABILITIES) (Dollars in millions) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Fixed-price contracts and other derivatives $ 54 $ 215 $ 8 $ 14 $ 46 $ 201 Deferred income taxes recoverable in rates 1,526 1,142 780 626 660 430 Pension and PBOP plan obligations (255) (212) 51 48 (306) (260) Employee benefit costs 24 24 3 3 21 21 Removal obligations (3,261) (3,082) (2,650) (2,468) (611) (614) Environmental costs 148 139 115 105 33 34 Sunrise Powerlink fire mitigation 123 124 123 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (223) (233) (223) (233) — — Commodity – gas, including transportation (179) (259) 46 52 (225) (311) Safety and reliability 1,192 959 276 207 916 752 Public purpose programs (442) (273) (200) (144) (242) (129) Wildfire mitigation plan 811 685 811 685 — — Liability insurance premium 107 113 79 90 28 23 Other balancing accounts 306 373 (70) (152) 376 525 Other regulatory (liabilities) assets, net (2) (188) (10) (5) 49 (181) (58) Total $ (257) $ (295) $ (856) $ (994) $ 515 $ 614 (1) At September 30, 2024 and December 31, 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $2,090 and $1,913, respectively, for SDG&E was $979 and $950, respectively, and for SoCalGas was $1,111 and $963, 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) Sempra SDG&E SoCalGas September 30, December 31, September 30, December 31, September 30, December 31, Fixed-price contracts and other derivatives $ 54 $ 215 $ 8 $ 14 $ 46 $ 201 Deferred income taxes recoverable in rates 1,526 1,142 780 626 660 430 Pension and PBOP plan obligations (255) (212) 51 48 (306) (260) Employee benefit costs 24 24 3 3 21 21 Removal obligations (3,261) (3,082) (2,650) (2,468) (611) (614) Environmental costs 148 139 115 105 33 34 Sunrise Powerlink fire mitigation 123 124 123 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (223) (233) (223) (233) — — Commodity – gas, including transportation (179) (259) 46 52 (225) (311) Safety and reliability 1,192 959 276 207 916 752 Public purpose programs (442) (273) (200) (144) (242) (129) Wildfire mitigation plan 811 685 811 685 — — Liability insurance premium 107 113 79 90 28 23 Other balancing accounts 306 373 (70) (152) 376 525 Other regulatory (liabilities) assets, net (2) (188) (10) (5) 49 (181) (58) Total $ (257) $ (295) $ (856) $ (994) $ 515 $ 614 (1) At September 30, 2024 and December 31, 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $2,090 and $1,913, respectively, for SDG&E was $979 and $950, respectively, and for SoCalGas was $1,111 and $963, 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	AUTHORIZED COST OF CAPITAL FOR 2023 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. On September 30, 2023, the CCM was triggered for SDG&E and SoCalGas. In December 2023, the CPUC approved the following authorized rates of return effective January 1, 2024. AUTHORIZED COST OF CAPITAL FOR 2024 SDG&E SoCalGas Authorized weighting Return on Weighted Authorized weighting Return on Weighted 45.25 % 4.34 % 1.96 % Long-Term Debt 45.60 % 4.54 % 2.07 % 2.75 6.22 0.17 Preferred Equity 2.40 6.00 0.14 52.00 10.65 5.54 Common Equity 52.00 10.50 5.46 100.00 % 7.67 % 100.00 % 7.67 %

SEMPRA - INVESTMENTS IN UNCON_2

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	9 Months Ended
	Sep. 30, 2024
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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Operating revenues $ 1,660 $ 1,592 $ 4,610 $ 4,227 Operating expenses (1,109) (1,007) (3,203) (3,007) Income from operations 551 585 1,407 1,220 Interest expense (170) (140) (481) (396) Income tax expense (75) (81) (179) (148) Net income 320 376 791 672 NCI held by Texas Transmission Investment LLC (63) (75) (157) (135) Earnings attributable to Sempra (1) 257 301 634 537 (1)

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	9 Months Ended
	Sep. 30, 2024
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	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) September 30, 2024 Borrower Expiration date of facility Total facility Commercial paper outstanding Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2029 (1) $ 4,000 $ (350) $ — $ — $ 3,650 SDG&E October 2029 (1) 1,500 (384) — — 1,116 SoCalGas October 2029 (1) 1,200 — — — 1,200 SI Partners and IEnova September 2025 500 — (390) — 110 SI Partners and IEnova August 2026 1,000 — — — 1,000 SI Partners and IEnova August 2028 1,500 — (551) — 949 Port Arthur LNG March 2030 200 — — (64) 136 Total $ 9,900 $ (734) $ (941) $ (64) $ 8,161 (1) In October 2024, Sempra, SDG&E and SoCalGas each amended their respective credit facility to extend the expiration date from October 2028 to October 2029. UNCOMMITTED LETTERS OF CREDIT OUTSTANDING (Dollars in millions) Expiration date range September 30, 2024 SDG&E January 2025 - November 2025 $ 26 SoCalGas October 2024 - November 2025 20 Other Sempra October 2024 - November 2054 445 Total Sempra $ 491 The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES September 30, 2024 December 31, 2023 Sempra 5.54 % 5.96 % SDG&E 4.95 — SoCalGas 5.82 5.44

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2024
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 September 30, 2024 December 31, 2023 Sempra: Natural gas MMBtu 455 361 Electricity MWh — 1 Congestion revenue rights MWh 16 36 SDG&E: Natural gas MMBtu 18 17 Congestion revenue rights MWh 16 36 SoCalGas: Natural gas MMBtu 405 268
Notional Amounts of Derivatives Table	The following table presents the notional amounts of our interest rate derivatives, excluding those in our equity method investments. INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Cash flow hedges (1) $ 3,571 2024-2034 $ 4,451 2024-2048 Undesignated derivatives (2) 4,163 2026-2048 — — (1) At September 30, 2024, cash flow hedges include Port Arthur LNG interest rate swaps with a maximum notional amount of $3,286 that mature in March 2026. At September 30, 2024 and December 31, 2023, cash flow hedges accrued interest based on a notional amount of $1,422 and $488, respectively. (2) At September 30, 2024, undesignated derivatives consist of Port Arthur LNG de-designated interest rate swaps with a maximum notional amount of $4,163 that begin hedging interest payments in March 2026. The following table presents the notional amounts of our foreign currency derivatives, excluding those in our equity method investments. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Foreign currency derivatives $ 201 2024-2026 $ 176 2024-2025
Derivative Instruments on the Condensed Consolidated Balance Sheets Table	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. We discuss the fair value of derivative assets and liabilities in Note 8. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2024 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 $ 14 $ 23 $ — $ (3) Foreign exchange instruments 5 1 (1) — Derivatives not designated as hedging instruments: Interest rate instruments — 40 — — Commodity contracts not subject to rate recovery 22 37 (17) (47) Associated offsetting commodity contracts (14) (26) 14 26 Commodity contracts subject to rate recovery 5 7 (52) (14) Associated offsetting commodity contracts (2) (3) 2 3 Associated offsetting cash collateral — — 9 5 Net amounts presented on the balance sheet 30 79 (45) (30) Additional cash collateral for commodity contracts not subject to rate recovery 55 — — — Additional cash collateral for commodity contracts subject to rate recovery 26 — — — Total (2) $ 111 $ 79 $ (45) $ (30) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ 7 $ (11) $ (8) Associated offsetting commodity contracts (1) (3) 1 3 Associated offsetting cash collateral — — 9 5 Net amounts presented on the balance sheet 3 4 (1) — Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (2) $ 27 $ 4 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 1 $ — $ (41) $ (6) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet — — (40) (6) Additional cash collateral for commodity contracts subject to rate recovery 2 — — — Total $ 2 $ — $ (40) $ (6) (1) Included in Other Current Assets for SDG&E and 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, 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 $ 17 $ 70 $ — $ — Foreign exchange instruments — — (9) — Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 173 52 (170) (56) Associated offsetting commodity contracts (169) (51) 169 51 Commodity contracts subject to rate recovery 10 8 (228) (9) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 12 7 Net amounts presented on the balance sheet 26 77 (221) (5) Additional cash collateral for commodity contracts not subject to rate recovery 74 — — — Additional cash collateral for commodity contracts subject to rate recovery 22 — — — Total (2) $ 122 $ 77 $ (221) $ (5) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 9 $ 8 $ (18) $ (9) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 12 7 Net amounts presented on the balance sheet 4 6 (1) — Additional cash collateral for commodity contracts subject to rate recovery 21 — — — Total (2) $ 25 $ 6 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 1 $ — $ (210) $ — Net amounts presented on the balance sheet 1 — (210) — Additional cash collateral for commodity contracts subject to rate recovery 1 — — — Total $ 2 $ — $ (210) $ — (1) Included in Other Current Assets for SDG&E and 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 hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI. HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain Pretax gain (loss) reclassified Three months ended September 30, Three months ended September 30, 2024 2023 Location 2024 2023 Sempra: Cash flow hedges: Interest rate instruments $ (203) $ 320 Interest expense $ 3 $ (1) Interest rate instruments (33) 32 Equity earnings (1) 5 12 Foreign exchange instruments 2 8 Other income, net 1 1 Foreign exchange instruments 2 7 Equity earnings (1) 1 1 Fair value hedges: Foreign exchange instruments (3) — Equity earnings (1) — — Total $ (235) $ 367 $ 10 $ 13 Nine months ended September 30, Nine months ended September 30, 2024 2023 Location 2024 2023 Sempra: Cash flow hedges: Interest rate instruments $ 5 $ 337 Interest expense $ 9 $ (1) Interest rate instruments (8) 56 Equity earnings (1) 20 33 Foreign exchange instruments 14 — Revenues: Energy- related businesses 5 — Other income, net 2 (1) Foreign exchange instruments 12 1 Equity earnings (1) 5 (1) Interest rate and foreign exchange instruments — 7 Interest expense — 1 Other income, net — 6 Fair value hedges: Foreign exchange instruments (10) — Equity earnings (1) — — Total $ 13 $ 401 $ 41 $ 37 SoCalGas: Cash flow hedges: Interest rate instruments $ — $ — Interest expense $ (1) $ (1) (1) Equity earnings at Oncor Holdings and 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 September 30, Nine months ended Location 2024 2023 2024 2023 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-related businesses $ 98 $ 83 $ 218 $ 785 Commodity contracts subject to rate recovery Cost of natural gas (16) (125) (43) (172) Commodity contracts subject to rate recovery Cost of electric fuel and purchased power (10) 23 (29) 5 Interest rate instrument Interest expense — — — (47) Total $ 72 $ (19) $ 146 $ 571 SDG&E: Commodity contracts subject to rate recovery Cost of electric fuel and purchased power $ (10) $ 23 $ (29) $ 5 SoCalGas: Commodity contracts subject to rate recovery Cost of natural gas $ (16) $ (125) $ (43) $ (172)

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2024
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures	RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 15 $ 3 $ — $ 18 Equity securities 315 4 — 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 45 25 — 70 Municipal bonds — 287 — 287 Other securities — 231 — 231 Total debt securities 45 543 — 588 Total nuclear decommissioning trusts (2) 375 550 — 925 Short-term investments held in Rabbi Trust 59 — — 59 Support Agreement, net of related guarantee fees — — 24 24 Interest rate instruments — 77 — $ — 77 Foreign exchange instruments — 6 — — 6 Commodity contracts not subject to rate recovery 6 53 — 15 74 Commodity contracts subject to rate recovery 4 2 6 21 33 Total $ 444 $ 688 $ 30 $ 36 $ 1,198 Liabilities: Interest rate instruments $ — $ 3 $ — $ — $ 3 Foreign exchange instruments — 1 — — 1 Commodity contracts not subject to rate recovery — 64 — (40) 24 Commodity contracts subject to rate recovery 18 48 — (19) 47 Total $ 18 $ 116 $ — $ (59) $ 75 Fair value at December 31, 2023 Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 19 $ 2 $ — $ 21 Equity securities 308 4 — 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 34 17 — 51 Municipal bonds — 275 — 275 Other securities — 220 — 220 Total debt securities 34 512 — 546 Total nuclear decommissioning trusts (2) 361 518 — 879 Short-term investments held in Rabbi Trust 67 — — 67 Support Agreement, net of related guarantee fees — — 23 23 Interest rate instruments — 87 — $ — 87 Commodity contracts not subject to rate recovery — 5 — 74 79 Commodity contracts subject to rate recovery — 1 10 22 33 Total $ 428 $ 611 $ 33 $ 96 $ 1,168 Liabilities: Foreign exchange instruments $ — $ 9 $ — $ — $ 9 Commodity contracts not subject to rate recovery — 6 — — 6 Commodity contracts subject to rate recovery 20 210 — (19) 211 Total $ 20 $ 225 $ — $ (19) $ 226 (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. (2) Excludes receivables (payables), net. RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 15 $ 3 $ — $ 18 Equity securities 315 4 — 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 45 25 — 70 Municipal bonds — 287 — 287 Other securities — 231 — 231 Total debt securities 45 543 — 588 Total nuclear decommissioning trusts (2) 375 550 — 925 Commodity contracts subject to rate recovery 4 1 6 $ 20 31 Total $ 379 $ 551 $ 6 $ 20 $ 956 Liabilities: Commodity contracts subject to rate recovery $ 18 $ 1 $ — $ (18) $ 1 Fair value at December 31, 2023 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 19 $ 2 $ — $ 21 Equity securities 308 4 — 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 34 17 — 51 Municipal bonds — 275 — 275 Other securities — 220 — 220 Total debt securities 34 512 — 546 Total nuclear decommissioning trusts (2) 361 518 — 879 Commodity contracts subject to rate recovery — — 10 $ 21 31 Total $ 361 $ 518 $ 10 $ 21 $ 910 Liabilities: Commodity contracts subject to rate recovery $ 20 $ — $ — $ (19) $ 1 (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. (2) Excludes receivables (payables), net. RECURRING FAIR VALUE MEASURES (Dollars in millions) Level 1 Level 2 Level 3 Netting (1) Total Fair value at September 30, 2024 SoCalGas: Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 47 $ — $ (1) $ 46 Fair value at December 31, 2023 SoCalGas: Assets: Commodity contracts subject to rate recovery $ — $ 1 $ — $ 1 $ 2 Liabilities: Commodity contracts subject to rate recovery $ — $ 210 $ — $ — $ 210 (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 classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) Three months ended September 30, 2024 2023 Balance at July 1 $ 6 $ 20 Realized and unrealized gains (losses), net (3) (2) Allocated transmission instruments 1 1 Settlements 2 (1) Balance at September 30 $ 6 $ 18 Change in unrealized gains relating to instruments still held at September 30 $ — $ 1 Nine months ended September 30, 2024 2023 Balance at January 1 $ 10 $ 35 Realized and unrealized gains (losses), net (6) (10) Allocated transmission instruments 1 (1) Settlements 1 (6) Balance at September 30 $ 6 $ 18 Change in unrealized losses relating to instruments still held at September 30 $ (1) $ (8) (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. 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. LEVEL 3 RECONCILIATIONS (Dollars in millions) Three months ended September 30, 2024 2023 Balance at July 1 $ 23 $ 23 Realized and unrealized gains (losses), net (1) 3 (3) Settlements (2) (2) Balance at September 30 (2) $ 24 $ 18 Change in unrealized gains (losses) relating to instruments still held at September 30 $ 3 $ (2) Nine months ended September 30, 2024 2023 Balance at January 1 $ 23 $ 17 Realized and unrealized gains (losses), net (1) 7 7 Settlements (6) (6) Balance at September 30 (2) $ 24 $ 18 Change in unrealized gains relating to instruments still held at September 30 $ 6 $ 7 (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 $17 in Other Long-term Assets at September 30, 2024 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 2024 $ (3.69) to $ 9.55 $ (0.44) 2023 (3.09) to 10.71 (0.56)
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 September 30, 2024 Sempra: Long-term note receivable (1) $ 347 $ — $ — $ 339 $ 339 Long-term amounts due to unconsolidated affiliates 347 — 326 — 326 Total long-term debt (2) 31,224 — 29,765 — 29,765 SDG&E: Total long-term debt (3) $ 8,950 $ — $ 8,247 $ — $ 8,247 SoCalGas: Total long-term debt (4) $ 7,359 $ — $ 7,220 $ — $ 7,220 December 31, 2023 Sempra: Long-term note receivable (1) $ 334 $ — $ — $ 318 $ 318 Long-term amounts due to unconsolidated affiliates 312 — 283 — 283 Total long-term debt (2) 27,716 — 25,617 — 25,617 SDG&E: Total long-term debt (3) $ 8,750 $ — $ 7,856 $ — $ 7,856 SoCalGas: Total long-term debt (4) $ 6,759 $ — $ 6,442 $ — $ 6,442 (1) Before allowances for credit losses of $5 and $6 at September 30, 2024 and December 31, 2023, respectively. Excludes unamortized transaction costs of $3 and $4 at September 30, 2024 and December 31, 2023, respectively. (2) After the effects of interest rate swaps. Before reductions of unamortized discount and debt issuance costs of $366 and $322 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,318 and $1,340 at September 30, 2024 and December 31, 2023, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $97 and $89 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,209 and $1,233 at September 30, 2024 and December 31, 2023, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $68 and $55 at September 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $109 and $107 at September 30, 2024 and December 31, 2023, respectively.

SEMPRA - EQUITY AND EARNINGS _2

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE (Tables)	9 Months Ended
	Sep. 30, 2024
Earnings Per Share [Abstract]
Schedule of Other Ownership Interests	The following table summarizes net income attributable to Sempra and transfers (to) from NCI, which shows the effects of changes in Sempra’s ownership interest in its subsidiaries on Sempra’s shareholders’ equity. NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI (Dollars in millions) Three months ended Nine months ended September 30, 2023 Sempra: Net income attributable to Sempra $ 732 $ 2,327 Transfers (to) from NCI: Decrease in shareholders’ equity for sales of NCI (62) (44) Net transfers (to) from NCI (62) (44) Change from net income attributable to Sempra and transfers (to) from NCI $ 670 $ 2,283
Schedule of Earnings Per Share, Basic and Diluted	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra: Numerator: Earnings attributable to common shares $ 638 $ 721 $ 2,152 $ 2,293 Denominator: Weighted-average common shares outstanding for basic EPS (1) 633,752 630,036 633,342 629,963 Dilutive effect of common shares sold forward 2,312 — 1,375 — Dilutive effect of stock options and RSUs (2) 1,997 2,288 1,849 2,268 Weighted-average common shares outstanding for diluted EPS 638,061 632,324 636,566 632,231 EPS: Basic $ 1.01 $ 1.14 $ 3.40 $ 3.64 Diluted $ 1.00 $ 1.14 $ 3.38 $ 3.63 (1) Includes 615 and 716 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2024 and 2023, respectively, and 616 and 716 of such RSUs for the nine months ended September 30, 2024 and 2023, 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)

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	9 Months Ended
	Sep. 30, 2024
Public Utilities, General Disclosures [Abstract]
Schedule of Nuclear Decommissioning Trusts Investments	Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E 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 September 30, 2024 Short-term investments, primarily cash equivalents $ 18 $ — $ — $ 18 Equity securities 80 241 (2) 319 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 69 1 — 70 Municipal bonds (2) 290 3 (6) 287 Other securities (3) 233 4 (6) 231 Total debt securities 592 8 (12) 588 Receivables (payables), net (19) — — (19) Total $ 671 $ 249 $ (14) $ 906 December 31, 2023 Short-term investments, primarily cash equivalents $ 21 $ — $ — $ 21 Equity securities 89 225 (2) 312 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 50 2 (1) 51 Municipal bonds 280 3 (8) 275 Other securities 228 3 (11) 220 Total debt securities 558 8 (20) 546 Receivables (payables), net (7) — — (7) Total $ 661 $ 233 $ (22) $ 872 (1) Maturity dates are 2025 - 2055. (2) Maturity dates are 2024 - 2062. (3) Maturity dates are 2024 - 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 September 30, Nine months ended September 30, 2024 2023 2024 2023 Proceeds from sales $ 259 $ 143 $ 639 $ 437 Gross realized gains 17 12 41 20 Gross realized losses 2 3 7 9

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	9 Months Ended
	Sep. 30, 2024
Commitments and Contingencies Disclosure [Abstract]
Lessor Information on the Condensed Consolidated Statements of Operations	We provide information below for leases for which we are the lessor. LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 Sempra – Sales-type leases: Interest income $ 1 $ 2 $ 4 $ 5 Total revenues from sales-type leases (1) $ 1 $ 2 $ 4 $ 5 Sempra – Operating leases: Fixed lease payments $ 83 $ 78 $ 259 $ 234 Variable lease payments 9 10 29 26 Total revenues from operating leases (1) $ 92 $ 88 $ 288 $ 260 Depreciation expense $ 17 $ 15 $ 53 $ 45 (1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations.

SEMPRA - SEGMENT INFORMATION (T

SEMPRA - SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2024
Segment Reporting [Abstract]
Segment Information	The following tables show selected information by segment from our Condensed Consolidated Balance Sheets, Condensed Consolidated Statements of Cash Flows and Condensed Consolidated Statements of Operations. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations. SEGMENT INFORMATION (Dollars in millions) September 30, December 31, ASSETS Sempra California $ 56,220 $ 53,430 Sempra Texas Utilities 15,292 14,392 Sempra Infrastructure 21,828 19,430 All other 1,434 967 Intersegment receivables (1,026) (1,038) Total $ 93,748 $ 87,181 EQUITY METHOD AND OTHER INVESTMENTS Sempra Texas Utilities $ 15,280 $ 14,380 Sempra Infrastructure 2,291 2,129 All other 1 1 Total $ 17,572 $ 16,510 Nine months ended September 30, 2024 2023 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT Sempra California $ 3,329 $ 3,344 Sempra Infrastructure 2,433 2,725 All other 3 5 Total $ 5,765 $ 6,074 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2024 2023 2024 2023 REVENUES Sempra California $ 2,256 $ 2,725 $ 8,022 $ 10,840 Sempra Infrastructure 538 629 1,466 2,485 Adjustments and eliminations (1) 1 (1) (1) Intersegment revenues (1) (17) (21) (60) (95) Total $ 2,776 $ 3,334 $ 9,427 $ 13,229 DEPRECIATION AND AMORTIZATION Sempra California $ 536 $ 491 $ 1,585 $ 1,435 Sempra Infrastructure 76 71 221 210 All other 2 1 5 6 Total $ 614 $ 563 $ 1,811 $ 1,651 INTEREST INCOME Sempra California $ 4 $ 9 $ 12 $ 19 Sempra Infrastructure 7 4 19 25 All other 6 7 17 17 Intercompany eliminations — (1) (1) (1) Total $ 17 $ 19 $ 47 $ 60 INTEREST EXPENSE Sempra California $ 213 $ 196 $ 627 $ 577 Sempra Texas Utilities 1 — 1 — Sempra Infrastructure — 7 — 127 All other 116 109 319 292 Intercompany eliminations (2) — (3) (1) Total $ 328 $ 312 $ 944 $ 995 INCOME TAX (BENEFIT) EXPENSE Sempra California $ (37) $ (20) $ 90 $ 64 Sempra Texas Utilities 1 — 1 — Sempra Infrastructure (43) 24 (67) 555 All other (26) (56) (87) (120) Total $ (105) $ (52) $ (63) $ 499 EQUITY EARNINGS Equity earnings, before income tax: Sempra Texas Utilities $ 2 $ 2 $ 6 $ 5 Sempra Infrastructure 130 131 420 413 132 133 426 418 Equity earnings, net of income tax: Sempra Texas Utilities 261 305 646 548 Sempra Infrastructure 61 41 163 120 322 346 809 668 Total $ 454 $ 479 $ 1,235 $ 1,086 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES Sempra California $ 247 $ 290 $ 1,145 $ 1,247 Sempra Texas Utilities 261 305 646 548 Sempra Infrastructure 230 223 652 746 All other (100) (97) (291) (248) Total $ 638 $ 721 $ 2,152 $ 2,293 (1) Revenues for reportable segments include intersegment revenues of $6 and $11 for the three months ended September 30, 2024 and $16 and $44 for the nine months ended September 30, 2024; $5 and $16 for the three months ended September 30, 2023 and $14 and $81 for the nine months ended September 30, 2023 for Sempra California and Sempra Infrastructure, respectively.

GENERAL INFORMATION AND OTHER_4

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	9 Months Ended
	Sep. 30, 2024 segment
Segment Reporting Information [Line Items]
Number of reportable segments	3
SDG&E
Segment Reporting Information [Line Items]
Number of reportable segments	1
SoCalGas
Segment Reporting Information [Line Items]
Number of reportable segments	1
Sempra California
Segment Reporting Information [Line Items]
Number of reportable segments	1

GENERAL INFORMATION AND OTHER_5

GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 USD ($)	Dec. 31, 2023 USD ($)		Jul. 01, 2020 project_owner
Variable Interest Entities [Line Items]
Property plant and equipment, net	$ 59,275	$ 54,960	[1]
Finance lease obligations	1,318	1,340
Equity method investment	15,160	14,266	[1]
Assets	93,748	87,181	[1]
Oncor Holdings | Sempra Texas Utilities
Variable Interest Entities [Line Items]
Equity method investment	15,160	14,266
Cameron LNG Holdings | Sempra Infrastructure
Variable Interest Entities [Line Items]
Equity method investment	1,068	1,008
SDG&E
Variable Interest Entities [Line Items]
Property plant and equipment, net	24,628	23,549	[1]
Finance lease obligations	1,209	1,233
Assets	$ 30,765	29,185	[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%
Cameron LNG JV
Variable Interest Entities [Line Items]
Number of project owners | project_owner				4
Variable Interest Entity, Not Primary Beneficiary | SDG&E
Variable Interest Entities [Line Items]
Property plant and equipment, net	$ 1,144	1,166
Finance lease obligations	1,144	1,166
Variable Interest Entity, Primary Beneficiary | ECA LNG JV | Sempra Infrastructure
Variable Interest Entities [Line Items]
Assets	1,715	1,580
Liabilities	1,060	1,029
Variable Interest Entity, Primary Beneficiary | Port Arthur LNG | Sempra Infrastructure
Variable Interest Entities [Line Items]
Assets	5,446	3,927
Liabilities	$ 865	$ 600
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_6

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023		Sep. 30, 2023	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 560	$ 236	[1]
Restricted cash, current	22	49	[1]
Restricted cash, noncurrent	108	104	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 690	$ 389		$ 1,491	$ 462
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_7

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 533	$ 181
Provisions for expected credit losses	149	374
Write-offs	(169)	(74)
Ending balance	513	481
Allowance for credit losses	5		$ 6
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	441		480
Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	57		52
Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	15		1
Other long-term assets | KKR Pinnacle
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	5		6
Deferred credits and other | Sempra Infrastructure
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses	5		5
SDG&E
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	144	78
Provisions for expected credit losses	46	96
Write-offs	(63)	(34)
Ending balance	127	140
SDG&E | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	94		116
SDG&E | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	26		27
SDG&E | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	7		1
SoCalGas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	331	98
Provisions for expected credit losses	70	276
Write-offs	(107)	(40)
Ending balance	294	$ 334
SoCalGas | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	255		306
SoCalGas | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	31		25
SoCalGas | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	$ 8		$ 0

GENERAL INFORMATION AND OTHER_8

GENERAL INFORMATION AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	$ 14	$ 31	[1]
Total due to unconsolidated affiliates – noncurrent	(347)	(307)	[1]
Related Party
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	14	31
Total due to unconsolidated affiliates – current	0	(5)	[1]
Total due to unconsolidated affiliates – noncurrent	(347)	(307)
Various affiliates
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	6	6
Tax Sharing Arrangement | Related Party
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	8	25
TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	0	(5)
SDG&E
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	8	0	[1]
SDG&E | Related Party
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	8	0
Total due to unconsolidated affiliates – current	(48)	(73)	[1]
SDG&E | Various affiliates
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(8)	(8)
SDG&E | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(40)	(44)
Income taxes due from Sempra	251	246
SDG&E | Due to/from SoCalGas
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	8	0
Total due to unconsolidated affiliates – current	0	(21)
SoCalGas
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	2	22	[1]
SoCalGas | Related Party
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	2	22
Total due to unconsolidated affiliates – current	(43)	(38)	[1]
SoCalGas | Various affiliates
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	2	1
SoCalGas | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(35)	(38)
Income taxes due from Sempra	9	6
SoCalGas | Due to/from SDG&E
Related Party Transaction [Line Items]
Total due from unconsolidated affiliates – current	0	21
Total due to unconsolidated affiliates – current	(8)	0
Five Point Five Percent Note Due January 2024 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	$ 0	(5)
Stated rate of debt (as a percent)	5.50%
Five Point Five Percent Note Due January 2025 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ 0	(24)
Five Point Five Percent Notes Due July 2025 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ 0	(23)
Five Point Five Percent Note due January 2026 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (8)	(20)
Five Point Five Percent Note due July 2026 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (12)	(11)
Five Point Five Percent Note due January 2027 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (15)	(14)
Five Point Five Percent Note due July 2027 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (18)	(17)
Five Point Five Percent Note due January 2028 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (47)	0
Five Point Five Percent Note due July 2028 | TAG Pipeline | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Total due to unconsolidated affiliates – noncurrent	$ (41)	0
Five Point Seven Four Percent Note December 2029 | TAG JV Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.74%
Total due to unconsolidated affiliates – noncurrent	$ (206)	$ (198)
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_9

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Related Party Transaction [Line Items]
Revenues	$ 2,776	$ 3,334	$ 9,427	$ 13,229
Interest expense	328	312	944	995
Related Party
Related Party Transaction [Line Items]
Revenues	11	10	31	34
Interest expense	5	3	12	11
SDG&E
Related Party Transaction [Line Items]
Revenues	1,243	1,442	3,977	4,357
Interest expense	131	126	390	367
Operating revenues	1,243	1,442	3,977	4,357
SDG&E | Related Party
Related Party Transaction [Line Items]
Operating revenues	6	5	17	15
Cost of sales	36	25	111	82
SoCalGas
Related Party Transaction [Line Items]
Revenues	1,054	1,313	4,168	6,574
Interest expense	82	70	237	210
Operating revenues	1,054	1,313	4,168	6,574
SoCalGas | Related Party
Related Party Transaction [Line Items]
Operating revenues	43	29	124	91
Cost of sales	$ (2)	$ 2	$ (5)	$ 37

GENERAL INFORMATION AND OTHE_10

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Inventory [Line Items]
Natural gas	$ 166	$ 174
LNG	13	9
Materials and supplies	340	299
Total	519	482	[1]
SDG&E
Inventory [Line Items]
Natural gas	1	1
LNG	0	0
Materials and supplies	181	152
Total	182	153	[1]
SoCalGas
Inventory [Line Items]
Natural gas	153	155
LNG	0	0
Materials and supplies	130	122
Total	$ 283	$ 277	[1]
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_11

GENERAL INFORMATION AND OTHER FINANCIAL DATA - DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Dedicated assets in support of certain benefit plans	$ 585	$ 549	[1]
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_12

GENERAL INFORMATION AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details)	3 Months Ended
	Jun. 30, 2024	Mar. 31, 2024
SDG&E
Loss Contingencies [Line Items]
Amortization of prepaid insurance fund asset	25 years	15 years

GENERAL INFORMATION AND OTHE_13

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR Pinnacle - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Dec. 31, 2023	Nov. 30, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable issued			$ 300
Compound interest rate (as a percent)	5%
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable, net	$ 345	$ 332

GENERAL INFORMATION AND OTHE_14

GENERAL INFORMATION AND OTHER FINANCIAL DATA - GOODWILL (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Goodwill	$ 1,602	$ 1,602	[1]
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_15

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PROPERTY, PLANT AND EQUIPMENT (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 USD ($) segment
Sempra Infrastructure
Property, Plant and Equipment [Line Items]
Number of segments of pipeline | segment	2
Sempra Infrastructure | Guaymas-El Oro segment of the Sonora Pipeline
Property, Plant and Equipment [Line Items]
Property, plant and equipment | $	$ 404

GENERAL INFORMATION AND OTHE_16

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	$ 166	$ 128	$ 466	$ 311
SDG&E
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	27	28	80	90
SoCalGas
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	$ 25	$ 20	$ 75	$ 55

GENERAL INFORMATION AND OTHE_17

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024		Sep. 30, 2023
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			$ 28,675
Total other comprehensive income (loss), net of tax amount, attributable to parent		$ (64)	$ 107	(35)		$ 121
Ending balance		29,703		29,703
AOCI associated with noncontrolling interests		(176)	202	(13)		212
Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(121)	(121)	(150)		(135)
OCI before reclassifications		(61)	111	(25)		132
Amounts reclassified from AOCI		(3)	(50)	(10)		(57)
Total other comprehensive income (loss), net of tax amount, attributable to parent		(64)	61	(35)		75
Ending balance		(185)	(60)	(185)		(60)
Foreign currency translation adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(49)	(38)	(36)		(59)
OCI before reclassifications		(12)	(5)	(25)		16
Amounts reclassified from AOCI		0	0	0		0
Total other comprehensive income (loss), net of tax amount, attributable to parent		(12)	(5)	(25)		16
Ending balance		(61)	(43)	(61)		(43)
Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		35	14	3		10
OCI before reclassifications		(49)	116	(1)		129
Amounts reclassified from AOCI		(5)	(51)	(21)		(60)
Total other comprehensive income (loss), net of tax amount, attributable to parent		(54)	65	(22)		69
Ending balance		(19)	79	(19)		79
AOCI associated with noncontrolling interests			(46)			(46)
Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(107)	(97)	(117)		(86)
OCI before reclassifications		0	0	1		(13)
Amounts reclassified from AOCI		2	1	11		3
Total other comprehensive income (loss), net of tax amount, attributable to parent		2	1	12		(10)
Ending balance		(105)	(96)	(105)		(96)
SDG&E
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		10,311	9,509	9,902	[1]	9,067
Ending balance		10,347	9,683	10,347		9,683
SDG&E | Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(8)	(7)	(8)		(7)
Ending balance		(8)	(7)	(8)		(7)
SDG&E | Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(8)	(7)	(8)		(7)
Ending balance		(8)	(7)	(8)		(7)
SoCalGas
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		7,901	7,215	7,410	[1]	6,698
Total other comprehensive income (loss), net of tax amount, attributable to parent			0	2		2
Ending balance		7,887	7,231	7,887		7,231
SoCalGas | Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(21)	(22)	(23)		(24)
Amounts reclassified from AOCI				2		2
Total other comprehensive income (loss), net of tax amount, attributable to parent				2		2
Ending balance		(21)	(22)	(21)		(22)
SoCalGas | Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(10)	(11)	(11)		(12)
Amounts reclassified from AOCI				1		1
Total other comprehensive income (loss), net of tax amount, attributable to parent				1		1
Ending balance		(10)	(11)	(10)		(11)
SoCalGas | Pension and PBOP
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(11)	(11)	(12)		(12)
Amounts reclassified from AOCI				1		1
Total other comprehensive income (loss), net of tax amount, attributable to parent				1		1
Ending balance		$ (11)	$ (11)	$ (11)		$ (11)
[1] Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_18

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (328)	$ (312)	$ (944)	$ (995)
Energy-related businesses	512	596	1,360	2,338
Other income, net	65	3	194	75
Income before income taxes and equity earnings	200	323	1,213	2,175
Income tax benefit (expense)	105	52	63	(499)
Net income	759	854	2,511	2,762
Earnings attributable to noncontrolling interests	(110)	(122)	(325)	(435)
Net income attributable to Sempra	649	732	2,186	2,327
SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(82)	(70)	(237)	(210)
Other income, net	13	(2)	73	(9)
Income before income taxes and equity earnings	(66)	11	477	600
Income tax benefit (expense)	52	5	(1)	(68)
Net income	(14)	16	476	532
Net income attributable to Sempra	(14)	16	476	532
SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(131)	(126)	(390)	(367)
Other income, net	30	25	86	75
Income before income taxes and equity earnings	276	259	759	712
Income tax benefit (expense)	(15)	15	(89)	4
Net income	261	274	670	716
Net income attributable to Sempra	261	274	670	716
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income attributable to Sempra	(3)	(4)	(10)	(11)
Reclassification out of Accumulated Other Comprehensive Income | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income attributable to Sempra			2	2
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	(10)	(13)	(41)	(37)
Income tax benefit (expense)	3	2	9	5
Net income	(7)	(11)	(32)	(32)
Net income attributable to Sempra	(5)	(5)	(21)	(14)
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]
Interest expense	(3)	1	(9)	1
Equity earnings	(5)	(12)	(20)	(33)
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest | Interest rate instruments | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense			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)	(1)	(5)	1
Energy-related businesses			(5)	0
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]
Interest expense			0	(1)
Other income, net			0	(6)
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	2	6	11	18
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net	2	1	5	2
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	1	1	2	2
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net			1	1
Reclassification out of Accumulated Other Comprehensive Income | Settlement charges
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net			9	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	3	2	16	4
Income tax benefit (expense)	(1)	(1)	(5)	(1)
Net income	$ 2	$ 1	$ 11	$ 3

GENERAL INFORMATION AND OTHE_19

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Pension
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 34	$ 25	$ 99	$ 82
Interest cost	41	39	124	118
Expected return on assets	(40)	(42)	(131)	(127)
Amortization of:
Prior service cost (credit)	1	2	4	4
Actuarial loss (gain)	4	3	10	7
Settlement charges			9	0
Net periodic benefit cost (credit)	40	27	115	84
Regulatory adjustments	20	30	21	88
Total expense (income) recognized	60	57	136	172
Pension | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Service cost	10	8	29	24
Interest cost	10	10	32	30
Expected return on assets	(10)	(9)	(33)	(29)
Amortization of:
Actuarial loss (gain)	3	2	6	4
Net periodic benefit cost (credit)	13	11	34	29
Regulatory adjustments	0	3	(7)	11
Total expense (income) recognized	13	14	27	40
Pension | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Service cost	21	15	59	49
Interest cost	26	24	78	75
Expected return on assets	(29)	(29)	(90)	(89)
Amortization of:
Prior service cost (credit)	1	1	3	3
Actuarial loss (gain)	1	1	1	1
Net periodic benefit cost (credit)	20	12	51	39
Regulatory adjustments	20	27	28	77
Total expense (income) recognized	40	39	79	116
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	3	11	10
Interest cost	9	9	27	28
Expected return on assets	(19)	(17)	(53)	(52)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(4)	(5)	(12)	(17)
Settlement charges			0	0
Net periodic benefit cost (credit)	(11)	(11)	(29)	(33)
Regulatory adjustments	10	10	28	32
Total expense (income) recognized	(1)	(1)	(1)	(1)
PBOP | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	1	2	2
Interest cost	3	2	6	6
Expected return on assets	(3)	(2)	(7)	(6)
Amortization of:
Actuarial loss (gain)	0	0	(1)	(1)
Net periodic benefit cost (credit)	0	1	0	1
Regulatory adjustments	0	(1)	0	(1)
Total expense (income) recognized	0	0	0	0
PBOP | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	2	8	7
Interest cost	7	7	21	21
Expected return on assets	(15)	(14)	(45)	(44)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(4)	(5)	(10)	(15)
Net periodic benefit cost (credit)	(10)	(11)	(28)	(33)
Regulatory adjustments	10	11	28	33
Total expense (income) recognized	$ 0	$ 0	$ 0	$ 0

GENERAL INFORMATION AND OTHE_20

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME (EXPENSE), NET (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Other Income [Line Items]
Allowance for equity funds used during construction	$ 39	$ 35	$ 114	$ 105
Investment gains (losses), net	29	(19)	48	(2)
Gains on interest rate and foreign exchange instruments, net	1	1	2	5
Foreign currency transaction (losses) gains, net	(5)	(3)	(6)	1
Non-service components of net periodic benefit cost	(21)	(28)	(25)	(79)
Interest on regulatory balancing accounts, net	26	19	68	56
Sundry, net	(4)	(2)	(7)	(11)
Total	65	3	194	75
SDG&E
Other Income [Line Items]
Allowance for equity funds used during construction	21	21	60	67
Non-service components of net periodic benefit cost	(3)	(5)	4	(14)
Interest on regulatory balancing accounts, net	12	10	30	31
Sundry, net	0	(1)	(8)	(9)
Total	30	25	86	75
SoCalGas
Other Income [Line Items]
Allowance for equity funds used during construction	18	14	54	38
Non-service components of net periodic benefit cost	(16)	(22)	(12)	(60)
Interest on regulatory balancing accounts, net	14	9	38	25
Sundry, net	(3)	(3)	(7)	(12)
Total	$ 13	$ (2)	$ 73	$ (9)

GENERAL INFORMATION AND OTHE_21

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (105)	$ (52)	$ (63)	$ 499
Income before income taxes and equity earnings	200	323	1,213	2,175
Equity earnings, before income tax:	132	133	426	418
Pretax income	$ 332	$ 456	$ 1,639	$ 2,593
Effective income tax rate (as a percent)	(32.00%)	(11.00%)	(4.00%)	19%
SDG&E
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 15	$ (15)	$ 89	$ (4)
Income before income taxes and equity earnings	$ 276	$ 259	$ 759	$ 712
Effective income tax rate (as a percent)	5%	(6.00%)	12%	(1.00%)
SoCalGas
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (52)	$ (5)	$ 1	$ 68
Income before income taxes and equity earnings	$ (66)	$ 11	$ 477	$ 600
Effective income tax rate (as a percent)	79%	(45.00%)	0%	11%

GENERAL INFORMATION AND OTHE_22

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES NARRATIVE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (105)	$ (52)	$ (63)	$ 499
SoCalGas
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (52)	$ (5)	$ 1	68
SoCalGas | Cumulative Effect, Period of Adoption, Adjustment [Member]
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)				$ 43

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,569	$ 2,894	$ 8,750	$ 11,675
Utilities regulatory revenues	(138)	197	(107)	76
Other revenues	345	243	784	1,478
Total revenues	2,776	3,334	9,427	13,229
SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,327	1,438	3,836	4,603
Utilities regulatory revenues	(84)	4	141	(246)
Total revenues	1,243	1,442	3,977	4,357
SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,110	1,120	4,416	6,252
Utilities regulatory revenues	(56)	193	(248)	322
Total revenues	1,054	1,313	4,168	6,574
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,402	2,541	8,174	10,815
Utilities | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,327	1,438	3,836	4,603
Utilities | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,110	1,120	4,416	6,252
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	167	353	576	860
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,314	1,506	5,302	7,750
Gas | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	167	182	658	988
Gas | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,110	1,120	4,416	6,252
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,255	1,388	3,448	3,925
Electric | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,160	1,256	3,178	3,615
Electric | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,394	2,528	8,129	10,764
Utilities regulatory revenues	(138)	197	(107)	76
Other revenues	0	0	0	0
Total revenues	2,256	2,725	8,022	10,840
Operating Segments | Sempra California | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,394	2,528	8,129	10,764
Operating Segments | Sempra California | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments | Sempra California | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,237	1,275	4,961	7,158
Operating Segments | Sempra California | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,157	1,253	3,168	3,606
Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	194	387	688	983
Utilities regulatory revenues	0	0	0	0
Other revenues	344	242	778	1,502
Total revenues	538	629	1,466	2,485
Operating Segments | Sempra Infrastructure | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	15	18	63	67
Operating Segments | Sempra Infrastructure | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	179	369	625	916
Operating Segments | Sempra Infrastructure | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	83	234	356	605
Operating Segments | Sempra Infrastructure | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	111	153	332	378
Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(19)	(21)	(67)	(72)
Utilities regulatory revenues	0	0	0	0
Other revenues	1	1	6	(24)
Total revenues	(18)	(20)	(61)	(96)
Consolidating adjustments and Parent and other | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(7)	(5)	(18)	(16)
Consolidating adjustments and Parent and other | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(12)	(16)	(49)	(56)
Consolidating adjustments and Parent and other | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(6)	(3)	(15)	(13)
Consolidating adjustments and Parent and other | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (13)	$ (18)	$ (52)	$ (59)

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Sep. 30, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 3,619
SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	72
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 90
Revenues to be recognized, period of recognition	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-10-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 0
Revenues to be recognized, period of recognition	3 months
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	$ 321
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
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	$ 321
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
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	$ 321
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
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	$ 253
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 2,313
Revenues to be recognized, period of recognition
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 56
Revenues to be recognized, period of recognition

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (198)	$ (252)
Revenue from performance obligations satisfied during reporting period	5	9
Payments received in advance	(3)	(21)
Contract liabilities, closing balance	(196)	(264)
Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(4)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(192)
SDG&E
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(75)	(79)
Revenue from performance obligations satisfied during reporting period	3	3
Contract liabilities, closing balance	(72)	$ (76)
SDG&E | Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(3)
SDG&E | Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ (69)

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,534	$ 1,970
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,490	1,951
Accounts receivable – trade, net | Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	223	148
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	20	15
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	4	4
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	20	0
SDG&E
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	899	889
SDG&E | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	867	870
SDG&E | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	19	13
SDG&E | Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	7	6
SDG&E | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	0
SoCalGas
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	572	987
SoCalGas | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	557	985
SoCalGas | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1	2
SoCalGas | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 14	$ 0

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (257)	$ (295)
Regulatory balancing accounts - net undercollected, Noncurrent	2,090	1,913
Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(255)	(212)
Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(3,261)	(3,082)
Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(223)	(233)
Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(179)	(259)
Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(442)	(273)
Other regulatory (liabilities) assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(188)	(10)
Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	54	215
Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	1,526	1,142
Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	24	24
Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	148	139
Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	123	124
Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	1,192	959
Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	811	685
Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	107	113
Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	306	373
SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(856)	(994)
Regulatory balancing accounts - net undercollected, Noncurrent	979	950
SDG&E | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,650)	(2,468)
SDG&E | Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(223)	(233)
SDG&E | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(200)	(144)
SDG&E | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(70)	(152)
SDG&E | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	8	14
SDG&E | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	780	626
SDG&E | Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	51	48
SDG&E | Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	3	3
SDG&E | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	115	105
SDG&E | Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	123	124
SDG&E | Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	46	52
SDG&E | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	276	207
SDG&E | Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	811	685
SDG&E | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	79	90
SDG&E | Other regulatory (liabilities) assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(5)	49
SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	515	614
Regulatory balancing accounts - net undercollected, Noncurrent	1,111	963
SoCalGas | Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(306)	(260)
SoCalGas | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(611)	(614)
SoCalGas | Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	0
SoCalGas | Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(225)	(311)
SoCalGas | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(242)	(129)
SoCalGas | Other regulatory (liabilities) assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(181)	(58)
SoCalGas | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	46	201
SoCalGas | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	660	430
SoCalGas | Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	21	21
SoCalGas | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	33	34
SoCalGas | Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	0
SoCalGas | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	916	752
SoCalGas | Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	0
SoCalGas | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	28	23
SoCalGas | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 376	$ 525

REGULATORY MATTERS - CPUC GRC N

REGULATORY MATTERS - CPUC GRC Narrative (Details) - USD ($) $ in Millions		1 Months Ended			9 Months Ended	12 Months Ended
	Oct. 18, 2024	Oct. 31, 2024	May 31, 2024	Oct. 31, 2023	Sep. 30, 2024	Dec. 31, 2025	Dec. 31, 2024
SDG&E | Subsequent Event | Forecast | California Public Utilities Commission
General Rate Case [Line Items]
Approved return on equity (as a percent)						10.23%
SoCalGas | Subsequent Event | Forecast | California Public Utilities Commission
General Rate Case [Line Items]
Approved return on equity (as a percent)						10.08%
2024 General Rate Case | Cost of Capital Proceeding
General Rate Case [Line Items]
Approved return on equity (as a percent)					50%
2024 General Rate Case | Cost of Capital Proceeding | Subsequent Event
General Rate Case [Line Items]
Change in benchmark rate during period percentage		20%
2024 General Rate Case | SDG&E | General Rate Case | California Public Utilities Commission
General Rate Case [Line Items]
Requested revenue requirements					$ 3,007
2024 General Rate Case | SDG&E | General Rate Case | Subsequent Event | California Public Utilities Commission
General Rate Case [Line Items]
Proposed revenue requirement	$ 2,800
Decrease in requested revenue requirement from prior years request	207
Revenue increase	$ 267
Requested percent increase	10.50%
Requested revenue requirement, annual increase, percentage	3.90%
2024 General Rate Case | SDG&E | General Rate Case | Subsequent Event | California Public Utilities Commission | Electrical Operations
General Rate Case [Line Items]
Proposed revenue requirement	$ 2,198
2024 General Rate Case | SDG&E | General Rate Case | Subsequent Event | California Public Utilities Commission | Natural Gas Operations
General Rate Case [Line Items]
Proposed revenue requirement	602
2024 General Rate Case | SDG&E | Cost of Capital Proceeding | Subsequent Event | California Public Utilities Commission
General Rate Case [Line Items]
Effect of approved decrease adjustment on ROE, percentage		0.42%
2024 General Rate Case | SoCalGas | General Rate Case | California Public Utilities Commission
General Rate Case [Line Items]
Requested revenue requirements			$ 4,434
2024 General Rate Case | SoCalGas | General Rate Case | Subsequent Event | California Public Utilities Commission
General Rate Case [Line Items]
Proposed revenue requirement	4,062
Decrease in requested revenue requirement from prior years request	372
Revenue increase	$ 523
Requested percent increase	14.80%
Requested revenue requirement, annual increase, percentage	3.90%
2024 General Rate Case | SoCalGas | Cost of Capital Proceeding | Subsequent Event | California Public Utilities Commission
General Rate Case [Line Items]
Effect of approved decrease adjustment on ROE, percentage		(0.42%)
2024 GRC - 2024 Requirement | SDG&E | General Rate Case
General Rate Case [Line Items]
Requested review and recovery of wildfire mitigation plan				$ 1,500
2024 GRC - 2024 Requirement | SDG&E | General Rate Case | Forecast
General Rate Case [Line Items]
General rate case, expected recovery of wildlife mitigation plan costs						$ 96
2024 GRC - 2024 Requirement | SDG&E | General Rate Case | Subsequent Event | Forecast
General Rate Case [Line Items]
General rate case, expected recovery of wildlife mitigation plan costs							$ 194

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL (Details) - California Public Utilities Commission	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
SDG&E
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)			100%
Weighted return on rate base (as a percent)			7.18%
SDG&E | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	10.23%
Authorized weighting (as a percent)		100%
Weighted return on rate base (as a percent)		7.67%
SDG&E | Authorized weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			45.25%
SDG&E | Authorized weighting | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			2.75%
SDG&E | Authorized weighting | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			52%
SDG&E | Authorized weighting | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		45.25%
SDG&E | Authorized weighting | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		2.75%
SDG&E | Authorized weighting | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		52%
SDG&E | Return on rate base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			4.05%
SDG&E | Return on rate base | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			6.22%
SDG&E | Return on rate base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			9.95%
SDG&E | Return on rate base | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		4.34%
SDG&E | Return on rate base | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		6.22%
SDG&E | Return on rate base | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		10.65%
SDG&E | Weighted return on rate base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			1.83%
SDG&E | Weighted return on rate base | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			0.17%
SDG&E | Weighted return on rate base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			5.17%
SDG&E | Weighted return on rate base | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		1.96%
SDG&E | Weighted return on rate base | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		0.17%
SDG&E | Weighted return on rate base | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		5.54%
SoCalGas
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)			100%
Weighted return on rate base (as a percent)			7.10%
SoCalGas | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	10.08%
Authorized weighting (as a percent)		100%
Weighted return on rate base (as a percent)		7.67%
SoCalGas | Authorized weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			45.60%
SoCalGas | Authorized weighting | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			2.40%
SoCalGas | Authorized weighting | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			52%
SoCalGas | Authorized weighting | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		45.60%
SoCalGas | Authorized weighting | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		2.40%
SoCalGas | Authorized weighting | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		52%
SoCalGas | Return on rate base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			4.07%
SoCalGas | Return on rate base | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			6%
SoCalGas | Return on rate base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			9.80%
SoCalGas | Return on rate base | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		4.54%
SoCalGas | Return on rate base | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		6%
SoCalGas | Return on rate base | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		10.50%
SoCalGas | Weighted return on rate base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)			1.86%
SoCalGas | Weighted return on rate base | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			0.14%
SoCalGas | Weighted return on rate base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)			5.10%
SoCalGas | Weighted return on rate base | Forecast | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)		2.07%
SoCalGas | Weighted return on rate base | Forecast | Preferred Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		0.14%
SoCalGas | Weighted return on rate base | Forecast | Common Equity | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)		5.46%

REGULATORY MATTERS - FERC RATE

REGULATORY MATTERS - FERC RATE MATTERS (Details) - SDG&E	9 Months Ended
	Sep. 30, 2024	Oct. 31, 2024
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%
Subsequent Event
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio at or above, base (as a percent)		11.75%

SEMPRA - INVESTMENTS IN UNCON_3

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		9 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) bank projectOwner	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 654	$ 668
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]
Equity ownership interest (as a percent)			100%
Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Investments made during period			$ 10	11
Sempra Texas Utilities | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Investments made during period			578	270
Proceeds from distributions received			$ 314	323
Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity (in percentage)			50.20%
Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 24
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			17
Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			353	339
Sempra Infrastructure | Cameron LNG JV | Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Liability cap, amount			$ 979
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%
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
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
Liability cap, amount	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
Guarantees, carrying value			$ 18
Sempra Infrastructure | TAG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 62	36
Sempra Infrastructure | IMG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received				$ 6

SEMPRA - INVESTMENTS IN UNCON_4

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Schedule of Equity Method Investments [Line Items]
Interest expense	$ (328)	$ (312)	$ (944)	$ (995)
Income tax benefit (expense)	105	52	63	(499)
Net income	759	854	2,511	2,762
NCI held by Texas Transmission Investment LLC	(110)	(122)	(325)	(435)
Earnings attributable to common shares	638	721	2,152	2,293
Equity Method Investment, Nonconsolidated Investee or Group of Investees | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,660	1,592	4,610	4,227
Operating expenses	(1,109)	(1,007)	(3,203)	(3,007)
Income from operations	551	585	1,407	1,220
Interest expense	(170)	(140)	(481)	(396)
Income tax benefit (expense)	(75)	(81)	(179)	(148)
Net income	320	376	791	672
NCI held by Texas Transmission Investment LLC	(63)	(75)	(157)	(135)
Earnings attributable to common shares	$ 257	$ 301	$ 634	$ 537

DEBT AND CREDIT FACILITIES - NA

DEBT AND CREDIT FACILITIES - NARRATIVE (Details) $ in Millions	1 Months Ended				9 Months Ended
	Sep. 30, 2024 USD ($) bank business_day line_of_credit	Aug. 31, 2024 USD ($)	May 31, 2024 USD ($)	Mar. 31, 2024 USD ($)	Sep. 30, 2024 USD ($) line_of_credit bank business_day lineOfCredit	Jul. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900				$ 9,900
Primary committed lines of credit | lineOfCredit					7
Ratio of indebtedness to net capital (in percent)	0.65				0.65
Available unused credit	$ 8,161				$ 8,161
Other Long-Term Debt, 4.125% Junior Subordinated Notes Due 2052
Line of Credit Facility [Line Items]
Stated rate of debt (as a percent)	4.125%				4.125%
Other Long-Term Debt, 5.75% Junior Subordinated Notes Due 2079
Line of Credit Facility [Line Items]
Stated rate of debt (as a percent)	5.75%				5.75%
6.40% Junior Subordinated Notes And 6.875% Junior Subordinated Notes | Redemption period one
Line of Credit Facility [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)					100%
6.40% Junior Subordinated Notes And 6.875% Junior Subordinated Notes | Redemption period two
Line of Credit Facility [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)					102%
6.40% Junior Subordinated Notes, Due October 1, 2054
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)					2.632%
Debt amount	$ 1,250				$ 1,250
Stated rate of debt (as a percent)	6.40%				6.40%
Proceeds from debt issuance	$ 1,235
Unamortized debt issuance costs and discounts	$ 15				$ 15
Debt instrument, interest rate, period (in years)	5 years				5 years
Number of days before interest rate period | business_day	2				2
6.875% Junior Subordinated Notes, Due October 1, 2054
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)					2.789%
Debt amount			$ 500	$ 600
Stated rate of debt (as a percent)	6.875%				6.875%
Proceeds from debt issuance			489	593
Unamortized debt issuance costs and discounts			11	7
Accrued interest			$ 7
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,500				$ 1,500
Ratio of indebtedness to net capital (in percent)	0.65				0.65
Available unused credit	$ 1,116				$ 1,116
SDG&E | Secured Debt | 5.55% First Mortgage Bonds Due April 15, 2054
Line of Credit Facility [Line Items]
Debt amount				$ 600
Stated rate of debt (as a percent)				5.55%
Proceeds from debt issuance				$ 587
Unamortized debt issuance costs and discounts				13
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,200				$ 1,200
Ratio of indebtedness to net capital (in percent)	0.65				0.65
Available unused credit	$ 1,200				$ 1,200
SoCalGas | 364-Day Term Loan, Due May 22,2025 | Secured Overnight Financing Rate (SOFR) | Variable Rate Component One
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)			0.80%
SoCalGas | 364-Day Term Loan, Due May 22,2025 | Secured Overnight Financing Rate (SOFR) | Variable Rate Component Two
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)			0.10%
SoCalGas | Secured Debt | 5.6% First Mortgage Bonds, Due April 1, 2054
Line of Credit Facility [Line Items]
Debt amount		$ 600		$ 500
Stated rate of debt (as a percent)		5.05%		5.60%
Proceeds from debt issuance		$ 592		$ 491
Unamortized debt issuance costs and discounts		$ 8		$ 9
SoCalGas | Line of Credit | 364-Day Term Loan, Due May 22,2025 | Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500
Term of debt instrument (in years)			364 days
Proceeds from lines of credit			$ 300
Available unused credit			200
Line of credit facility, accordion feature, increase limit			$ 500
SI Partners
Line of Credit Facility [Line Items]
Maximum adjustment EBITDA allowed	5.25				5.25
SI Partners and IEnova
Line of Credit Facility [Line Items]
Number of lines of credit | line_of_credit	3				3
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 Facility [Line Items]
Debt outstanding	$ 420				$ 420		$ 258
Weighted average interest rate (as a percent)	5.33%				5.33%		5.81%
Port Arthur LNG | Domestic Line of Credit | Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 6,800				$ 6,800
Term of debt instrument (in years)					7 years
ECA LNG Phase 1 | Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)		1.54%
ECA LNG Phase 1 | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)		1.64%
ECA LNG Phase 1 | Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,300				$ 1,300
Term of debt instrument (in years)					5 years
Number of banks in syndicate | bank	7				7
Debt outstanding	$ 1,000				$ 1,000		$ 832
Weighted average interest rate (as a percent)	7.56%				7.56%		8.31%
ECA LNG Phase 1 | Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 100				$ 200
Line of credit, amount outstanding	$ 14				$ 14
Variable percentage rate (in percent)					0.10%

DEBT AND CREDIT FACILITIES - CO

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details) $ in Millions	Sep. 30, 2024 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900
Available unused credit	8,161
Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(64)
Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(734)
Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(941)
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity	4,000
Available unused credit	3,650
Sempra | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Sempra | Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(350)
Sempra | Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Available unused credit	1,116
SDG&E | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SDG&E | Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(384)
SDG&E | Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,200
Available unused credit	1,200
SoCalGas | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SoCalGas | Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SoCalGas | Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Maximum borrowing capacity	500
Available unused credit	110
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due September 2025 | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,000
Available unused credit	1,000
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due August 2026 | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Available unused credit	949
SI Partners and IEnova | IEnova and SI Partners Committed Line Of Credit Due August 2028 | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial paper outstanding | IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial paper outstanding | IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial paper outstanding | IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Amounts outstanding | IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Line of credit outstanding	(390)
SI Partners and IEnova | Amounts outstanding | IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Amounts outstanding | IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Line of credit outstanding	(551)
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	200
Available unused credit	136
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due 2030 | Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(64)
Port Arthur LNG | Commercial paper outstanding | Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Port Arthur LNG | Amounts outstanding | 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	Sep. 30, 2024 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,200
Uncommitted Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Letters of credit outstanding	491
Uncommitted Letters of Credit Outstanding | SDG&E
Line of Credit Facility [Line Items]
Letters of credit outstanding	26
Uncommitted Letters of Credit Outstanding | SoCalGas
Line of Credit Facility [Line Items]
Letters of credit outstanding	20
Uncommitted Letters of Credit Outstanding | Other Sempra
Line of Credit Facility [Line Items]
Letters of credit outstanding	$ 445

DEBT AND CREDIT FACILITIES - WE

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Sep. 30, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.54%	5.96%
SDG&E
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	4.95%	0%
SoCalGas
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.82%	5.44%

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2024 MMBTU MWh	Dec. 31, 2023 MWh MMBTU
Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	455	361
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	16	36
SDG&E | Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	18	17
SDG&E | Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	16	36
SoCalGas | Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	405	268

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES (Details) - Interest rate instruments - Port Arthur LNG - USD ($) $ in Millions	1 Months Ended	9 Months Ended
	Oct. 31, 2024	Sep. 30, 2024
Derivative [Line Items]
Deferred gains on derivative		$ 40
Subsequent Event
Derivative [Line Items]
Settlement of cross-currency swaps	$ 46
Notional amounts	$ 1,000

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE AND FOREIGN CURRENCY DERIVATIVES (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Interest rate swaps | Derivatives not designated as hedging instruments:
Derivative [Line Items]
Notional amount of derivative	$ 4,163	$ 0
Interest rate swaps | Derivatives not designated as hedging instruments: | Port Arthur LNG
Derivative [Line Items]
Notional amount of derivative	4,163
Foreign currency derivatives
Derivative [Line Items]
Notional amount of derivative	201	176
Cash Flow Hedging | Interest rate instruments
Derivative [Line Items]
Notional amount of derivative	3,571	4,451
Cash Flow Hedging | Interest rate swaps
Derivative [Line Items]
Notional amounts	1,422	$ 488
Cash Flow Hedging | Interest rate swaps | Port Arthur LNG
Derivative [Line Items]
Notional amount of derivative	$ 3,286

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	$ 30	$ 26
Derivative asset, Additional cash collateral for commodity contracts not subject to rate recovery	55	74
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	26	22
Derivative assets, Total	111	122
Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	79	77
Derivative asset, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	79	77
Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(45)	(221)
Derivative liability, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(45)	(221)
Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(30)	(5)
Derivative liability, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(30)	(5)
Derivatives designated as hedging instruments: | Other current assets | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	14	17
Derivatives designated as hedging instruments: | Other current assets | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	5	0
Derivatives designated as hedging instruments: | Other long-term assets | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	23	70
Derivatives designated as hedging instruments: | Other long-term assets | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	1	0
Derivatives designated as hedging instruments: | Other current liabilities | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	0
Derivatives designated as hedging instruments: | Other current liabilities | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(1)	(9)
Derivatives designated as hedging instruments: | Deferred credits and other | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(3)	0
Derivatives designated as hedging instruments: | Deferred credits and other | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	0
Derivatives not designated as hedging instruments: | Other current assets | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	0
Derivatives not designated as hedging instruments: | Other current assets | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	22	173
Derivative asset, subject to master netting arrangement, liability offset	(14)	(169)
Derivatives not designated as hedging instruments: | Other current assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	5	10
Derivative asset, subject to master netting arrangement, liability offset	(2)	(5)
Associated offsetting cash collateral	0	0
Derivatives not designated as hedging instruments: | Other long-term assets | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	40
Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	37	52
Derivative asset, subject to master netting arrangement, liability offset	(26)	(51)
Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	7	8
Derivative asset, subject to master netting arrangement, liability offset	(3)	(2)
Associated offsetting cash collateral	0	0
Derivatives not designated as hedging instruments: | Other current liabilities | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0
Derivatives not designated as hedging instruments: | Other current liabilities | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(17)	(170)
Derivative liability, subject to master netting arrangement, asset offset	14	169
Derivatives not designated as hedging instruments: | Other current liabilities | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(52)	(228)
Derivative liability, subject to master netting arrangement, asset offset	2	5
Associated offsetting cash collateral	9	12
Derivatives not designated as hedging instruments: | Deferred credits and other | Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0
Derivatives not designated as hedging instruments: | Deferred credits and other | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(47)	(56)
Derivative liability, subject to master netting arrangement, asset offset	26	51
Derivatives not designated as hedging instruments: | Deferred credits and other | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(14)	(9)
Derivative liability, subject to master netting arrangement, asset offset	3	2
Associated offsetting cash collateral	5	7
SDG&E | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	3	4
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	24	21
Derivative assets, Total	27	25
SDG&E | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	4	6
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	4	6
SDG&E | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(1)	(1)
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(1)	(1)
SDG&E | Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	0	0
SDG&E | Derivatives not designated as hedging instruments: | Other current assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	4	9
Derivative asset, subject to master netting arrangement, liability offset	(1)	(5)
Associated offsetting cash collateral	0	0
SDG&E | Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	7	8
Derivative asset, subject to master netting arrangement, liability offset	(3)	(2)
Associated offsetting cash collateral	0	0
SDG&E | Derivatives not designated as hedging instruments: | Other current liabilities | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(11)	(18)
Derivative liability, subject to master netting arrangement, asset offset	1	5
Associated offsetting cash collateral	9	12
SDG&E | Derivatives not designated as hedging instruments: | Deferred credits and other | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(8)	(9)
Derivative liability, subject to master netting arrangement, asset offset	3	2
Associated offsetting cash collateral	5	7
SoCalGas | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	0	1
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	2	1
Derivative assets, Total	2	2
SoCalGas | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	0	0
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	0	0
SoCalGas | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(40)	(210)
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(40)	(210)
SoCalGas | Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(6)	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(6)	0
SoCalGas | Derivatives not designated as hedging instruments: | Other current assets
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	(1)
SoCalGas | Derivatives not designated as hedging instruments: | Other current assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	1	1
SoCalGas | Derivatives not designated as hedging instruments: | Other long-term assets
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	0
SoCalGas | Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	0	0
SoCalGas | Derivatives not designated as hedging instruments: | Other current liabilities
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	1
SoCalGas | Derivatives not designated as hedging instruments: | Other current liabilities | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(41)	(210)
SoCalGas | Derivatives not designated as hedging instruments: | Deferred credits and other
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	0
SoCalGas | Derivatives not designated as hedging instruments: | Deferred credits and other | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	$ (6)	$ 0

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ (225)	$ 315	$ (24)	$ 321
Pretax gain (loss) on derivatives recognized in earnings	$ 1	$ 1	$ 2	$ 5
Interest rate instruments
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	INTEREST EXPENSE	INTEREST EXPENSE	INTEREST EXPENSE	INTEREST EXPENSE
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	Unregulated Operating Revenue	Unregulated Operating Revenue
Cost of 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	Cost of Goods and Services Sold	Cost of Goods and Services Sold
Cost of 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	Cost of Goods and Services Sold	Cost of Goods and Services Sold
Derivatives designated as hedging instruments:
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	$ (235)	$ 367	$ 13	$ 401
Pretax gain (loss) reclassified from AOCI into earnings	10	13	41	37
Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedging | Interest rate instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(203)	320	5	337
Pretax gain (loss) reclassified from AOCI into earnings	3	(1)	9	(1)
Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedging | Interest rate instruments | SoCalGas
Derivative [Line Items]
Pretax (loss) gain recognized in OCI			0	0
Pretax gain (loss) reclassified from AOCI into earnings			(1)	(1)
Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedging | Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI			0	7
Pretax gain (loss) reclassified from AOCI into earnings			0	1
Derivatives designated as hedging instruments: | Equity Earnings | Cash Flow Hedging | Interest rate instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(33)	32	(8)	56
Pretax gain (loss) reclassified from AOCI into earnings	5	12	20	33
Derivatives designated as hedging instruments: | Equity Earnings | Cash Flow Hedging | Foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	2	7	12	1
Pretax gain (loss) reclassified from AOCI into earnings	1	1	5	(1)
Derivatives designated as hedging instruments: | Equity Earnings | Fair Value Hedging | Foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(3)	0	(10)	0
Pretax gain (loss) reclassified from AOCI into earnings	0	0	0	0
Derivatives designated as hedging instruments: | Other income, net | Cash Flow Hedging | Foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	2	8
Pretax gain (loss) reclassified from AOCI into earnings	1	1	2	(1)
Derivatives designated as hedging instruments: | Other income, net | Cash Flow Hedging | Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings			0	6
Derivatives designated as hedging instruments: | Revenues: Energy- related businesses | Cash Flow Hedging | Foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI			14	0
Pretax gain (loss) reclassified from AOCI into earnings			5	0
Derivatives not designated as hedging instruments:
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	72	(19)	146	571
Derivatives not designated as hedging instruments: | Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	0	(47)
Derivatives not designated as hedging instruments: | Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	98	83	218	785
Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery | SoCalGas
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(16)	(125)	(43)	(172)
Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery | SDG&E
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(10)	23	(29)	5
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	(16)	(125)	(43)	(172)
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	$ (10)	$ 23	$ (29)	$ 5

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 USD ($)
Derivative [Line Items]
Cash flow hedge gains (losses) to be reclassified	$ 31
Cash flow hedge gains (losses) to be reclassified, NCI	$ 11
Term of interest rate cash flow hedge (in years)	1 year 6 months
SoCalGas
Derivative [Line Items]
Cash flow hedge gains (losses) to be reclassified	$ (1)

DERIVATIVE FINANCIAL INSTRUME_9

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES NARRATIVE (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Derivative [Line Items]
Derivative fair value	$ 114	$ 215
Collateral	114
SoCalGas
Derivative [Line Items]
Derivative fair value	46	$ 210
Collateral	$ 46

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	$ 925	$ 879
Short-term investments held in Rabbi Trust	59	67
Support Agreement, net of related guarantee fees	24	23
Netting adjustment	36	96
Total	1,198	1,168
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(59)	(19)
Total	75	226
Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	18	21
Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	319	312
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	70	51
Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	287	275
Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	231	220
Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	588	546
Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0	0
Derivative assets, Total	77	87
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	0
Derivative liabilities	3
Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	15	74
Derivative assets, Total	74	79
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(40)	0
Derivative liabilities	24	6
Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	21	22
Derivative assets, Total	33	33
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(19)	(19)
Derivative liabilities	47	211
Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0
Derivative assets, Total	6
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	0	0
Derivative liabilities	1	9
Level 1
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	375	361
Short-term investments held in Rabbi Trust	59	67
Support Agreement, net of related guarantee fees	0	0
Total	444	428
Liabilities, Fair Value Disclosure [Abstract]
Total	18	20
Level 1 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	15	19
Level 1 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	315	308
Level 1 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	45	34
Level 1 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 1 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 1 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	45	34
Level 1 | Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0
Level 1 | Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 1 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	4	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	18	20
Level 1 | Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 2
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	550	518
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	688	611
Liabilities, Fair Value Disclosure [Abstract]
Total	116	225
Level 2 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	2
Level 2 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	4	4
Level 2 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	25	17
Level 2 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	287	275
Level 2 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	231	220
Level 2 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	543	512
Level 2 | Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	77	87
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	3
Level 2 | Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	53	5
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	64	6
Level 2 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	2	1
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	48	210
Level 2 | Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	1	9
Level 3
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	24	23
Total	30	33
Liabilities, Fair Value Disclosure [Abstract]
Total	0	0
Level 3 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 | Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0
Level 3 | Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 3 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	10
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 3 | Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SDG&E
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	925	879
Netting adjustment	20	21
Total	956	910
SDG&E | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	18	21
SDG&E | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	319	312
SDG&E | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	70	51
SDG&E | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	287	275
SDG&E | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	231	220
SDG&E | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	588	546
SDG&E | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	20	21
Derivative assets, Total	31	31
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(18)	(19)
Derivative liabilities	1	1
SDG&E | Level 1
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	375	361
Total	379	361
SDG&E | Level 1 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	15	19
SDG&E | Level 1 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	315	308
SDG&E | Level 1 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	45	34
SDG&E | Level 1 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 1 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 1 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	45	34
SDG&E | Level 1 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	4	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	18	20
SDG&E | Level 2
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	550	518
Total	551	518
SDG&E | Level 2 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	2
SDG&E | Level 2 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	4	4
SDG&E | Level 2 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	25	17
SDG&E | Level 2 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	287	275
SDG&E | Level 2 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	231	220
SDG&E | Level 2 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	543	512
SDG&E | Level 2 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	1	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	1	0
SDG&E | Level 3
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Total	6	10
SDG&E | Level 3 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E | Level 3 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	10
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SoCalGas | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	1	1
Derivative assets, Total	2	2
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(1)	0
Derivative liabilities	46	210
SoCalGas | Level 1 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SoCalGas | Level 2 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	1	1
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	47	210
SoCalGas | Level 3 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	$ 0	$ 0

FAIR VALUE MEASUREMENTS - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2024 USD ($) $ / MWh	Sep. 30, 2023 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 6	$ 20	$ 10	$ 35
Realized and unrealized gains (losses), net	(3)	(2)	(6)	(10)
Allocated transmission instruments	1	1	1	(1)
Settlements	2	(1)	1	(6)
Ending balance	6	18	6	18
Change in unrealized gains relating to instruments still held at September 30	0	1	(1)	(8)
Other Sempra
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	23	23	23	17
Realized and unrealized gains (losses), net	3	(3)	7	7
Settlements	(2)	(2)	(6)	(6)
Ending balance	24	18	24	18
Change in unrealized gains (losses) relating to instruments still held at September 30	3	(2)	6	7
Other Sempra | Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Other Sempra | Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	17		17
SDG&E
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	6	20	10	35
Realized and unrealized gains (losses), net	(3)	(2)	(6)	(10)
Allocated transmission instruments	1	1	1	(1)
Settlements	2	(1)	1	(6)
Ending balance	6	18	6	18
Change in unrealized gains relating to instruments still held at September 30	$ 0	$ 1	$ (1)	$ (8)
Level 3 | SDG&E | Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh			(3.69)	(3.09)
Level 3 | SDG&E | Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh			9.55	10.71
Level 3 | SDG&E | 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			(0.44)	(0.56)

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Allowance for credit losses	$ 5	$ 6
Unamortized transaction costs	3	4
Unamortized discount and debt issuance costs	366	322
Finance lease obligations	1,318	1,340
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	347	334
Long-term amounts due to unconsolidated affiliates	347	312
Total long-term debt	31,224	27,716
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	339	318
Long-term amounts due to unconsolidated affiliates	326	283
Total long-term debt	29,765	25,617
Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note 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 note receivable	0	0
Long-term amounts due to unconsolidated affiliates	326	283
Total long-term debt	29,765	25,617
Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	339	318
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
SDG&E
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	97	89
Finance lease obligations	1,209	1,233
SDG&E | Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,950	8,750
SDG&E | Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,247	7,856
SDG&E | Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SDG&E | Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,247	7,856
SDG&E | Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SoCalGas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	68	55
Finance lease obligations	109	107
SoCalGas | Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,359	6,759
SoCalGas | Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,220	6,442
SoCalGas | Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SoCalGas | Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,220	6,442
SoCalGas | Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

SEMPRA - EQUITY AND EARNINGS _3

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - PREFERRED STOCK NARRATIVE (Details) - shares	Sep. 30, 2024	May 02, 2024	May 01, 2024	Dec. 31, 2023
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	50,000,000			50,000,000
Series A Preferred Stock
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)		0	17,250,000
Series B Preferred Stock
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)		0	5,750,000

SEMPRA - EQUITY AND EARNINGS _4

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - COMMON STOCK NARRATIVE (Details) $ / shares in Units, $ in Millions		1 Months Ended	9 Months Ended
	Aug. 02, 2023 shares	Nov. 30, 2023 $ / shares shares	Sep. 30, 2024 USD ($) shares	Sep. 30, 2023 USD ($) shares	Nov. 06, 2024 USD ($) shares	Dec. 31, 2023 shares
Equity, Class of Treasury Stock [Line Items]
Stock split, conversion ratio	2
Stock dividend (in percent)	100%
Common stock, shares authorized (in shares)	1,125,000,000		1,125,000,000			1,125,000,000
Common stock
Equity, Class of Treasury Stock [Line Items]
Share repurchase program, number of shares repurchased (in shares)			565,571	411,447
Common stock repurchased | $			$ 41	$ 32
Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Sale of stock, shares available for future settlement					17,142,858
Public Stock Offering
Equity, Class of Treasury Stock [Line Items]
Sale of stock, number of shares issued in transaction		19,242,010
Common stock, par or stated value per share (usd per share) | $ / shares		$ 0
Sale of stock, price per share (usd per share) | $ / shares		70
Sale of stock, price per share, after underwriting discounts (usd per share) | $ / shares		$ 68.845
Public Stock Offering Pursuant to Forward Sale Agreement
Equity, Class of Treasury Stock [Line Items]
Sale of stock, number of shares issued in transaction		17,142,858
At The Market Program Offering | Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Aggregate sales price | $					$ 3,000
Underwriting commission, percent					1%

SEMPRA - EQUITY AND EARNINGS _5

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Earnings Per Share [Abstract]
Net income attributable to Sempra	$ 649	$ 732	$ 2,186	$ 2,327
Decrease in shareholders’ equity for sales of NCI		(62)		(44)
Net transfers (to) from NCI		(62)		(44)
Change from net income attributable to Sempra and transfers (to) from NCI		$ 670		$ 2,283

SEMPRA - EQUITY AND EARNINGS _6

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NCI NARRATIVE (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2023	Mar. 31, 2023	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Noncontrolling Interest [Line Items]
Noncontrolling interest, increase from sale of parent equity interest				$ 986		$ 1,241
Contributions			$ 335	496	$ 1,121	1,091
Port Arthur LNG
Noncontrolling Interest [Line Items]
Contributions	$ 1,100	$ 234
SI Partners
Noncontrolling Interest [Line Items]
Noncontrolling interest, increase from sale of parent equity interest						200
Sale of noncontrolling interest, change in equity						145
Indirect Subsidiary Of SI Partners | Port Arthur LNG
Noncontrolling Interest [Line Items]
Noncontrolling interest, increase from sale of parent equity interest		12
Cash consideration	984	254
Noncontrolling interest, decrease from sale of parent equity interest	56
Noncontrolling interest, decrease from sale of parent equity interest, net of transaction costs	11
Noncontrolling interest, decrease from sale of parent equity interest, tax expense (benefit)	$ 22
Noncontrolling interest, increase from sale of parent equity interest, net of transaction costs		3
Noncontrolling interest, increase from sale of parent equity interest, tax expense (benefit)		5
Funding commitment, aggregate amount		$ 9,000
Funding commitment paid			$ 2,700		$ 2,700
KKR Pinnacle | SI Partners
Noncontrolling Interest [Line Items]
Funding used				$ 14		$ 200
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 | SI Partners | KKR Denali
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	42%			42%		42%
S I Partners Subsidiary | Indirect Subsidiary Of SI Partners | KKR Denali
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	60%			60%		60%

SEMPRA - EQUITY AND EARNINGS _7

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares, basic	$ 638	$ 721	$ 2,152	$ 2,293
Earnings attributable to common shares, diluted	$ 638	$ 721	$ 2,152	$ 2,293
Weighted-average common shares outstanding for basic EPS (in shares)	633,752,000	630,036,000	633,342,000	629,963,000
Dilutive effect of common shares sold forward (in shares)	2,312,000	0	1,375,000	0
Dilutive effect of stock options and RSUs (in shares)	1,997,000	2,288,000	1,849,000	2,268,000
Weighted-average common shares outstanding for diluted EPS (in shares)	638,061,000	632,324,000	636,566,000	632,231,000
Earnings per share, basic (dollars per share)	$ 1.01	$ 1.14	$ 3.40	$ 3.64
Earnings per share, diluted (in dollars per share)	$ 1	$ 1.14	$ 3.38	$ 3.63
Vested RSUs included in basic WASO (in shares)	615,000	716,000	616,000	716,000
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)			414,812
Performance-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			721,049
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			312,043
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	450,243	624,242	996,966	470,804

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - SDG&E - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Jointly Owned Utility Plant Interests [Line Items]
Nuclear liability insurance coverage, maximum	$ 500
Secondary financial protection, maximum	60
Secondary financial protection, company contribution, annual maximum	560
Nuclear property damage insurance	130
Federal nuclear property damage insurance, minimum required	50
Nuclear property insurance terrorism coverage, maximum	$ 3,240
Jointly Owned Nuclear Power Plant
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20%
Percent of dismantlement work expense (as a percent)	20%
Decommissioning costs	$ 480
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 79

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
Debt Securities, Available-for-sale [Line Items]
Cost	$ 671		$ 671		$ 661
Gross unrealized gains	249		249		233
Gross unrealized losses	(14)		(14)		(22)
Estimated fair value	906		906		872
Proceeds from sales	259	$ 143	639	$ 437
Gross realized gains	17	12	41	20
Gross realized losses	2	$ 3	7	$ 9
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	18		18		21
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	18		18		21
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	80		80		89
Gross unrealized gains	241		241		225
Gross unrealized losses	(2)		(2)		(2)
Estimated fair value	319		319		312
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	592		592		558
Gross unrealized gains	8		8		8
Gross unrealized losses	(12)		(12)		(20)
Estimated fair value	588		588		546
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	69		69		50
Gross unrealized gains	1		1		2
Gross unrealized losses	0		0		(1)
Estimated fair value	70		70		51
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	290		290		280
Gross unrealized gains	3		3		3
Gross unrealized losses	(6)		(6)		(8)
Estimated fair value	287		287		275
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	233		233		228
Gross unrealized gains	4		4		3
Gross unrealized losses	(6)		(6)		(11)
Estimated fair value	231		231		220
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(19)		(19)		(7)
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (19)		$ (19)		$ (7)

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - NARRATIVE (Details) £ in Millions, $ in Millions

1 Months Ended

3 Months Ended

4 Months Ended

9 Months Ended

12 Months Ended

48 Months Ended

Nov. 01, 2024 plaintiff claim lawsuit

Sep. 30, 2021 USD ($) plaintiff lawsuit

Sep. 30, 2024 USD ($)

Sep. 30, 2023 USD ($)

Feb. 11, 2016 well

Sep. 30, 2024 USD ($)

Sep. 30, 2023 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2023 GBP (£)

Dec. 31, 2022 USD ($)

Dec. 31, 2021 claimant lawsuit

Jul. 31, 2024 lawsuit

Aug. 31, 2023 Bcf

Dec. 31, 2015 company

Loss Contingencies [Line Items]

Liability for legal proceedings

$ 53

$ 53

Number of liquidating companies | company

10

Equity earnings

454

$ 479

1,235

$ 1,086

Sempra Infrastructure

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

2

Number of claimants | claimant

3

Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

390

Number of lawsuits | plaintiff

36,000

HMRC VAT Claim

Loss Contingencies [Line Items]

Damages awarded

$ 10

£ 7.9

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%

Non-Settling Individual Plaintiffs | Aliso Canyon Natural Gas Storage Facility Gas Leak | Subsequent Event

Loss Contingencies [Line Items]

Number of lawsuits | plaintiff

520

RBS Sempra Commodities

Loss Contingencies [Line Items]

Equity earnings

$ 40

SoCalGas

Loss Contingencies [Line Items]

Liability for legal proceedings

28

28

Wells with gas leak | well

1

Natural gas inventory level (in bcf) | Bcf

68.6

SoCalGas | Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

390

Number of lawsuits | plaintiff

36,000

Net book value of Aliso Canyon facility

1,000

1,000

SoCalGas | 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

SoCalGas | Non-Settling Individual Plaintiffs | Aliso Canyon Natural Gas Storage Facility Gas Leak | Subsequent Event

Loss Contingencies [Line Items]

Number of lawsuits | plaintiff

520

SDG&E

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

2

Energy Future Holdings Corp. | Subsequent Event

Loss Contingencies [Line Items]

Lawsuits pending | lawsuit

1

Number of proof of claims | claim

28,000

Deferred Credits and Other | Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Payable related to natural gas leak

1

1

Deferred Credits and Other | SoCalGas | Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Payable related to natural gas leak

1

1

Other current liabilities | Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Payable related to natural gas leak

21

21

Other current liabilities | SoCalGas | Aliso Canyon Natural Gas Storage Facility Gas Leak

Loss Contingencies [Line Items]

Payable related to natural gas leak

$ 21

$ 21

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION NARRATIVE (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 USD ($) agreement	Dec. 31, 2023 USD ($)	[1]
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 888	$ 723
SDG&E
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 542	368
SDG&E | Purchased-Power Contracts
Lessee, Lease, Description [Line Items]
Number of purchased-power contracts | agreement	6
Number of purchase power contracts to be commenced the remainder of the year | agreement	2
Number of purchase power contracts to be commenced in year one | agreement	2
Number of purchase power contracts to be commenced in year two | agreement	2
Future minimum lease payments due remainder of the year	$ 5
Future minimum lease payments due year one	41
Future minimum lease payments due year two	67
Future minimum lease payments due year three	68
Future minimum lease payments due year four	68
Future minimum lease payments due after year four	777
SDG&E | Energy Storage Tolling Agreements
Lessee, Lease, Description [Line Items]
Future minimum lease payments due remainder of the year	4
Future minimum lease payments due year one	23
Future minimum lease payments due year two	23
Future minimum lease payments due year three	23
Future minimum lease payments due year four	23
Future minimum lease payments due after year four	182
Right-of-use assets – operating leases	202
Operating Lease, Liability	202
Sempra Infrastructure | Tugboat Lease Agreement
Lessee, Lease, Description [Line Items]
Future minimum lease payments due year three	10
Future minimum lease payments due year four	12
Future minimum lease payments due after year four	210
Future minimum fixed payments	184
SoCalGas
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	20	$ 29
SoCalGas | Headquarters Lease Agreement
Lessee, Lease, Description [Line Items]
Future minimum lease payments due year four	8
Future minimum lease payments due after year four	143
Prepaid Expense	$ 1
[1] Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Interest income	$ 1	$ 2	$ 4	$ 5
Total revenues from sales-type leases	1	2	4	5
Fixed lease payments	83	78	259	234
Variable lease payments	9	10	29	26
Total revenues from operating leases	92	88	288	260
Depreciation expense	$ 17	$ 15	$ 53	$ 45

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS & ENVIRONMENTAL ISSUES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 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	$ 51
Sempra Infrastructure | Natural Gas Contracts And Transportation Commitments
Loss Contingencies [Line Items]
Increase (decrease) in unrecorded unconditional purchase obligation	474
Increase (decrease) in unrecorded unconditional purchase obligation, remainder of fiscal year	(17)
Increase (decrease) in unrecorded unconditional purchase obligation, year one	4
Increase (decrease) in unrecorded unconditional purchase obligation, year two	76
Increase (decrease) in unrecorded unconditional purchase obligation, year three	98
Increase (decrease) in unrecorded unconditional purchase obligation, year four	98
Increase (decrease) in unrecorded unconditional purchase obligation, after four years	215
Sempra Infrastructure | Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Increase (decrease) in unrecorded unconditional purchase obligation, remainder of fiscal year	(321)
Increase (decrease) in unrecorded unconditional purchase obligation, year one	(76)
Increase (decrease) in unrecorded unconditional purchase obligation, year two	(51)
Increase (decrease) in unrecorded unconditional purchase obligation, year three	(37)
Increase (decrease) in unrecorded unconditional purchase obligation, year four	(45)
Increase (decrease) in unrecorded unconditional purchase obligation, after four years	(30)
SDG&E
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	18
SoCalGas
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	20
SoCalGas | Natural Gas Contracts And Transportation Commitments
Loss Contingencies [Line Items]
Increase (decrease) in unrecorded unconditional purchase obligation	340
Increase (decrease) in unrecorded unconditional purchase obligation, remainder of fiscal year	(7)
Increase (decrease) in unrecorded unconditional purchase obligation, year one	36
Increase (decrease) in unrecorded unconditional purchase obligation, year two	111
Increase (decrease) in unrecorded unconditional purchase obligation, year three	119
Increase (decrease) in unrecorded unconditional purchase obligation, year four	$ 81

SEMPRA - SEGMENT INFORMATION -

SEMPRA - SEGMENT INFORMATION - NARRATIVE (Details)	9 Months Ended
	Sep. 30, 2024 segment
Segment Reporting Information [Line Items]
Number of reportable segments	3
Sempra Infrastructure | SI Partners
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	70%
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%

SEMPRA - SEGMENT INFORMATION _2

SEMPRA - SEGMENT INFORMATION - SCHEDULE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
Segment Reporting Information, Additional Information [Abstract]
ASSETS	$ 93,748		$ 93,748		$ 87,181	[1]
EQUITY METHOD AND OTHER INVESTMENTS	17,572		17,572		16,510
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			5,765	$ 6,074
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	2,776	$ 3,334	9,427	13,229
DEPRECIATION AND AMORTIZATION	614	563	1,811	1,651
INTEREST INCOME	17	19	47	60
INTEREST EXPENSE	328	312	944	995
INCOME TAX (BENEFIT) EXPENSE	(105)	(52)	(63)	499
Equity earnings, before income tax:	132	133	426	418
Equity earnings, net of income tax	322	346	809	668
Equity earnings	454	479	1,235	1,086
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	638	721	2,152	2,293
Operating Segments | Sempra California
Segment Reporting Information, Additional Information [Abstract]
ASSETS	56,220		56,220		53,430
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			3,329	3,344
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	2,256	2,725	8,022	10,840
DEPRECIATION AND AMORTIZATION	536	491	1,585	1,435
INTEREST INCOME	4	9	12	19
INTEREST EXPENSE	213	196	627	577
INCOME TAX (BENEFIT) EXPENSE	(37)	(20)	90	64
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	247	290	1,145	1,247
Operating Segments | Sempra Texas Utilities
Segment Reporting Information, Additional Information [Abstract]
ASSETS	15,292		15,292		14,392
EQUITY METHOD AND OTHER INVESTMENTS	15,280		15,280		14,380
Segment Reporting Information, Profit (Loss) [Abstract]
INTEREST EXPENSE	1	0	1	0
INCOME TAX (BENEFIT) EXPENSE	1	0	1	0
Equity earnings, before income tax:	2	2	6	5
Equity earnings, net of income tax	261	305	646	548
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	261	305	646	548
Operating Segments | Sempra Infrastructure
Segment Reporting Information, Additional Information [Abstract]
ASSETS	21,828		21,828		19,430
EQUITY METHOD AND OTHER INVESTMENTS	2,291		2,291		2,129
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			2,433	2,725
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	538	629	1,466	2,485
DEPRECIATION AND AMORTIZATION	76	71	221	210
INTEREST INCOME	7	4	19	25
INTEREST EXPENSE	0	7	0	127
INCOME TAX (BENEFIT) EXPENSE	(43)	24	(67)	555
Equity earnings, before income tax:	130	131	420	413
Equity earnings, net of income tax	61	41	163	120
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	230	223	652	746
All other
Segment Reporting Information, Additional Information [Abstract]
ASSETS	1,434		1,434		967
EQUITY METHOD AND OTHER INVESTMENTS	1		1		1
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			3	5
Segment Reporting Information, Profit (Loss) [Abstract]
DEPRECIATION AND AMORTIZATION	2	1	5	6
INTEREST INCOME	6	7	17	17
INTEREST EXPENSE	116	109	319	292
INCOME TAX (BENEFIT) EXPENSE	(26)	(56)	(87)	(120)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(100)	(97)	(291)	(248)
Adjustments and eliminations
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(1)	1	(1)	(1)
Intersegment revenues and eliminations
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,026)		(1,026)		$ (1,038)
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(17)	(21)	(60)	(95)
INTEREST INCOME	0	(1)	(1)	(1)
INTEREST EXPENSE	(2)	0	(3)	(1)
Intersegment revenues and eliminations | Sempra California
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	6	5	16	14
Intersegment revenues and eliminations | Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 11	$ 16	$ 44	$ 81
[1] Derived from audited financial statements.