Southern California Gas Company PFD 6% (SOCGM) 10-K 25 Feb 25 2024 FY Annual report Financial data

Cover

Cover - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2024	Feb. 19, 2025	Jun. 28, 2024
Document And Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 48.1
Entity Common Stock, Shares Outstanding		651,457,249
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Sempra proxy statement to be filed for its May 2025 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K. Portions of the Southern California Gas Company information statement to be filed for its June 2025 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K.
Entity Central Index Key	0001032208
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
SDG&E
Document And Entity Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	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 Public Float			0
Entity Central Index Key	0000086521
SoCalGas
Document And Entity Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West 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 Public Float			$ 0
Entity Central Index Key	0000092108
Common Stock
Document And Entity Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
5.75% Junior Subordinated Notes Due 2079
Document And Entity Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE
Preferred stock | SoCalGas
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, $25 par value
Preferred Stock Series A | SoCalGas
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, Series A, $25 par value

AUDIT INFORMATION

AUDIT INFORMATION	12 Months Ended
	Dec. 31, 2024
Auditor [Line Items]
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	San Diego, California
Auditor Firm ID	34
SDG&E
Auditor [Line Items]
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	San Diego, California
Auditor Firm ID	34
SoCalGas
Auditor [Line Items]
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	San Diego, California
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
Natural gas	$ 7,141	$ 9,495	$ 7,868
Electric	4,296	4,334	4,783
Energy-related businesses	1,748	2,891	1,788
Total revenues	13,185	16,720	14,439
EXPENSES AND OTHER INCOME
Operation and maintenance	(5,336)	(5,458)	(4,746)
Aliso Canyon litigation and regulatory matters	0	0	(259)
Depreciation and amortization	(2,437)	(2,227)	(2,019)
Franchise fees and other taxes	(693)	(677)	(635)
Other income, net	136	131	24
Interest income	61	89	75
Interest expense	(1,049)	(1,309)	(1,054)
Income before income taxes and equity earnings	2,110	2,627	1,343
Income tax expense	(219)	(490)	(556)
Equity earnings	1,609	1,481	1,498
Net income	3,500	3,618	2,285
Earnings attributable to noncontrolling interests	(638)	(543)	(146)
Preferred dividends	(44)	(44)	(44)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings attributable to common shares	$ 2,817	$ 3,030	$ 2,094
Basic EPS:
Earnings	$ 4.44	$ 4.81	$ 3.32
Weighted-average number of shares outstanding (in shares)	633,795	630,296	630,318
Diluted EPS:
Earnings	$ 4.42	$ 4.79	$ 3.31
Weighted Average Common Shares Outstanding	637,943	632,733	632,757
Cost of natural gas
EXPENSES AND OTHER INCOME
Operating expenses	$ (1,132)	$ (3,719)	$ (2,603)
Cost of electric fuel and purchased power
EXPENSES AND OTHER INCOME
Operating expenses	(245)	(375)	(937)
Energy-related businesses cost of sales
EXPENSES AND OTHER INCOME
Operating expenses	$ (380)	$ (548)	$ (942)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Comprehensive Income [Abstract]
Net income, pretax amount, attributable to parent	$ 3,081	$ 3,565	$ 2,695
Income tax (expense) benefit	(219)	(490)	(556)
Net income, after tax amount, attributable to parent	2,862	3,075	2,139
Net income, Non-controlling interest (after tax)	638	543	146
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	3,500	3,618	2,285
Foreign currency translation adjustments
Foreign currency translation adjustments, pretax amount, attributable to parent	(30)	23	11
Foreign currency translation adjustments, income tax (expense) benefit, attributable to parent	0	0	0
Foreign currency translation adjustments, net of tax amount, attributable to parent	(30)	23	11
Foreign currency translation adjustments, net of tax amount, attributable to noncontrolling interests	(14)	10	4
Total foreign currency translation adjustments	(44)	33	15
Financial instruments
Financial instruments, pretax amount, attributable to parent	14	57	221
Financial instruments, income tax (expense) benefit, attributable to parent	(2)	(18)	(55)
Financial instruments, net of tax amount, attributable to parent	12	39	166
Financial instruments, after tax amount, attributable to noncontrolling interests	25	(38)	50
Total financial instruments	37	1	216
Pension and other postretirement benefits
Pension and other postretirement benefits, pretax amount, attributable to parent	18	(39)	3
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(16)	8	(6)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	(31)	(3)
Pension and other postretirement benefits, net of tax amount, attributable to noncontrolling interests	0	0	0
Total pension and other postretirement benefits	2	(31)	(3)
Total other comprehensive income, pretax amount, attributable to parent	2	41	235
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(18)	(10)	(61)
Total other comprehensive income, net of tax amount, attributable to parent	(16)	31	174
Total other comprehensive income, net of tax amount, attributable to noncontrolling interests	11	(28)	54
Total other comprehensive income	(5)	3	228
Comprehensive income, pretax amount, attributable to parent	3,083	3,606	2,930
Comprehensive income, income tax (expense) benefit, attributable to parent	(237)	(500)	(617)
Comprehensive income, after tax amount, attributable to parent	2,846	3,106	2,313
Comprehensive income, after tax amount, attributable to noncontrolling interests	649	515	200
Total comprehensive income	3,495	3,621	2,513
Preferred dividends of subsidiary, pretax amount, attributable to parent	(1)	(1)	(1)
Preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	0	0	0
Preferred dividends of subsidiary, net of tax amount, attributable to parent	(1)	(1)	(1)
Preferred dividends of subsidiary, net of tax amount, attributable to noncontrolling interests	0	0	0
Total preferred dividends of subsidiary	(1)	(1)	(1)
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	3,082	3,605	2,929
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(237)	(500)	(617)
Comprehensive income, after preferred dividends of subsidiary	2,845	3,105	2,312
Comprehensive income, after preferred dividends of subsidiary, net of tax amount, attributable to noncontrolling interest	649	515	200
Total comprehensive income, after preferred dividends of subsidiary	$ 3,494	$ 3,620	$ 2,512

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 1,565	$ 236
Restricted cash	21	49
Accounts receivable – trade, net	1,983	2,151
Accounts receivable – other, net	397	561
Due from unconsolidated affiliates	13	31
Income taxes receivable	90	94
Inventories	559	482
Prepaid expenses	255	273
Regulatory assets	60	226
Fixed-price contracts and other derivatives	91	122
Greenhouse gas allowances	217	1,189
Other current assets	34	56
Total current assets	5,285	5,470
Other assets:
Restricted cash	3	104
Regulatory assets	3,937	3,771
Greenhouse gas allowances	845	301
Nuclear decommissioning trusts	875	872
Dedicated assets in support of certain benefit plans	585	549
Deferred income taxes	172	129
Right-of-use assets – operating leases	1,177	723
Investment in Oncor Holdings	15,400	14,266
Other investments	2,534	2,244
Goodwill	1,602	1,602
Other intangible assets	292	318
Wildfire fund	262	269
Other long-term assets	1,749	1,603
Total other assets	29,433	26,751
Property, plant and equipment:
Property, plant and equipment	80,397	72,495
Less accumulated depreciation and amortization	(18,960)	(17,535)
Property, plant and equipment, net	61,437	54,960
Total assets	96,155	87,181
Current liabilities:
Short-term debt	2,016	2,342
Accounts payable – trade	2,238	2,211
Accounts payable – other	208	224
Dividends and interest payable	773	691
Accrued compensation and benefits	558	526
Regulatory liabilities	141	553
Current portion of long-term debt and finance leases	2,274	975
Greenhouse gas obligations	217	1,189
Total current liabilities	9,676	10,090
Long-term debt and finance leases	31,558	27,759
Deferred credits and other liabilities:
Due to unconsolidated affiliates	352	307
Regulatory liabilities	3,817	3,739
Greenhouse gas obligations	506	0
Pension and other postretirement benefit plan obligations, net of plan assets	168	407
Deferred income taxes	5,845	5,254
Asset retirement obligations	3,737	3,642
Deferred credits and other	2,708	2,329
Total deferred credits and other liabilities	17,133	15,678
Commitments and contingencies
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock	13,520	12,204
Retained earnings	16,979	15,732
Accumulated other comprehensive income (loss)	(166)	(150)
Total shareholders’ equity	31,222	28,675
Preferred stock of subsidiary	20	20
Other noncontrolling interests	6,546	4,959
Total equity	37,788	33,654
Total liabilities and shareholders’ equity	96,155	87,181
Preferred Class C
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	889	889
Nonrelated Party
Current liabilities:
Other current liabilities	1,251	1,374
Related Party
Current assets:
Due from unconsolidated affiliates	13	31
Current liabilities:
Other current liabilities	0	5
Deferred credits and other liabilities:
Due to unconsolidated affiliates	$ 352	$ 307

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
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)	650,629,876	631,431,732	628,669,356	633,839,564
Preferred Class C
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 3,500	$ 3,618	$ 2,285
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	2,437	2,227	2,019
Deferred income taxes and investment tax credits	(20)	249	392
Equity earnings	(1,609)	(1,481)	(1,498)
Share-based compensation expense	86	80	71
Fixed-price contracts and other derivatives	(197)	(666)	863
Bad debt expense	209	458	122
Other	20	(14)	56
Net change in working capital components:
Accounts receivable	118	168	(976)
Due to/from unconsolidated affiliates, net	30	26	(31)
Income taxes receivable/payable, net	(49)	142	(29)
Inventories	(74)	(80)	(17)
Other current assets	(30)	11	(1,608)
Accounts payable	(131)	(270)	430
Regulatory balancing accounts, net	(456)	260	36
Reserve for Aliso Canyon costs	(12)	(98)	(1,851)
Other current liabilities	142	1,270	228
Insurance receivable for Aliso Canyon costs	0	0	360
Distributions from investments	1,093	912	854
Changes in other noncurrent assets and liabilities, net	(150)	(594)	(564)
Net cash provided by operating activities	4,907	6,218	1,142
Net cash used in investing activities
Expenditures for property, plant and equipment	(8,215)	(8,397)	(5,357)
Expenditures for investments	(988)	(382)	(376)
Return on investments	9	0	0
Purchases of nuclear decommissioning and other trust assets	(889)	(610)	(700)
Proceeds from sales of nuclear decommissioning and other trust assets	942	661	762
Repayments of advances to unconsolidated affiliates	0	0	626
Other	23	12	6
Net cash used in investing activities	(9,118)	(8,716)	(5,039)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,499)	(1,483)	(1,430)
Preferred dividends paid	(44)	(44)	(44)
Issuances of common stock, net	1,219	145	4
Repurchases of common stock	(43)	(32)	(478)
Issuances of debt (maturities greater than 90 days)	8,674	7,669	9,984
Payments on debt (maturities greater than 90 days) and finance leases	(3,339)	(6,294)	(4,510)
(Decrease) increase in short-term debt, net	(557)	552	(1,266)
Advances from unconsolidated affiliates	85	31	28
Proceeds from sales of noncontrolling interests, net	0	1,219	1,732
Distributions to noncontrolling interests	(297)	(730)	(237)
Contributions from noncontrolling interests	1,235	1,570	31
Termination of interest rate and settlement of cross-currency swaps	46	(99)	0
Other	(56)	(85)	(35)
Net cash provided by financing activities	5,424	2,419	3,779
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(13)	6	(1)
Increase (decrease) in cash, cash equivalents and restricted cash	1,200	(73)	(119)
Cash, cash equivalents and restricted cash, January 1	389	462	581
Cash, cash equivalents and restricted cash, December 31	1,589	389	462
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Interest payments, net of amounts capitalized	1,205	1,172	1,014
Income tax payments, net of refunds	289	197	284
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Accrued interest receivable capitalized to note receivable	17	16	16
Repayments of advances from unconsolidated affiliate in lieu of distributions	62	36	32
Accrued capital expenditures for PP&E	1,181	1,052	590
Capital expenditures reclassed from assets to PP&E	53	18	5
Increase in finance lease obligations capitalized to PP&E	41	57	57
Amortized debt issuance costs capitalized to PP&E	13	4	0
Unamortized debt issuance costs reclassed from assets to debt	27	9	0
Accrued interest payable capitalized to due to unconsolidated affiliate	16	0	0
Increase in ARO capitalized to PP&E	1	33	91
Common dividends issued in stock	54	0	0
Net exercise of stock options	9	0	0
Contributions from NCI	0	200	0
Common Stock
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Dividends declared but not paid	393	376	360
Preferred stock
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Dividends declared but not paid	$ 11	$ 11	$ 11

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Preferred stock	Common stock	Retained earnings	Accumulated other comprehensive income (loss)	Sempra shareholders' equity	Non- controlling interests	Preferred Class C	Preferred Class C Retained earnings	Preferred Class C Sempra shareholders' equity
Beginning Balance at Dec. 31, 2021	$ 27,419	$ 889	$ 11,862	$ 13,548	$ (318)	$ 25,981	$ 1,438
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,285			2,139		2,139	146
Other comprehensive income (loss)	228				174	174	54
Share-based compensation expense	71		71			71
Dividends [Abstract]
Preferred dividends								$ (44)	$ (44)	$ (44)
Common stock dividends	(1,441)			(1,441)		(1,441)
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of common stock	4		4			4
Repurchases of common stock	(478)		(478)			(478)
Noncontrolling Interest Items [Abstract]
Contributions	31						31
Distributions	(237)						(237)
Sales	1,419		701		9	710	709
Ending balance at Dec. 31, 2022	29,256	889	12,160	14,201	(135)	27,115	2,141
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,618			3,075		3,075	543
Other comprehensive income (loss)	3				31	31	(28)
Share-based compensation expense	80		80			80
Dividends [Abstract]
Preferred dividends								(44)	(44)	(44)
Common stock dividends	(1,499)			(1,499)		(1,499)
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of common stock	144		144			144
Repurchases of common stock	(32)		(32)			(32)
Noncontrolling Interest Items [Abstract]
Contributions	1,625		(145)			(145)	1,770
Distributions	(730)						(730)
Sales	1,234		(3)		(46)	(49)	1,283
Ending balance at Dec. 31, 2023	33,654	889	12,204	15,732	(150)	28,675	4,979
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,500			2,862		2,862	638
Other comprehensive income (loss)	(5)				(16)	(16)	11
Share-based compensation expense	86		86			86
Dividends [Abstract]
Preferred dividends								$ (44)	$ (44)	$ (44)
Common stock dividends	(1,570)			(1,570)		(1,570)
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of common stock	1,273		1,273			1,273
Repurchases of common stock	(43)		(43)			(43)
Noncontrolling Interest Items [Abstract]
Contributions	1,235						1,235
Distributions	(297)						(297)
Ending balance at Dec. 31, 2024	$ 37,788	$ 889	$ 13,520	$ 16,979	$ (166)	$ 31,222	$ 6,566

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Dividends declared per share of common stock (in dollars per share)	$ 2.48	$ 2.38	$ 2.29
Preferred Class C
Dividends declared per share of preferred stock (in dollars per share)	$ 48.75	$ 48.75	$ 48.75

STATEMENTS OF OPERATIONS - SDG&

STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
Electric	$ 4,296	$ 4,334	$ 4,783
Natural gas	7,141	9,495	7,868
Operating expenses:
Other income, net	136	131	24
Interest income	61	89	75
Interest expense	(1,049)	(1,309)	(1,054)
Income before income taxes and equity earnings	2,110	2,627	1,343
Income tax (expense) benefit	(219)	(490)	(556)
Net income	3,500	3,618	2,285
Earnings attributable to common shares	2,817	3,030	2,094
SDG&E
REVENUES
Electric	4,313	4,349	4,795
Natural gas	1,028	1,248	1,043
Total operating revenues	5,341	5,597	5,838
Operating expenses:
Cost of electric fuel and purchased power	308	445	994
Cost of natural gas	242	532	363
Operation and maintenance	1,692	1,846	1,677
Depreciation and amortization	1,223	1,098	982
Franchise fees and other taxes	402	381	373
Total operating expenses	3,867	4,302	4,389
Operating Income	1,474	1,295	1,449
Other income, net	90	97	92
Interest income	5	15	5
Interest expense	(525)	(497)	(449)
Income before income taxes and equity earnings	1,044	910	1,097
Income tax (expense) benefit	(153)	26	(182)
Net income	891	936	915
Earnings attributable to common shares	$ 891	$ 936	$ 915

STATEMENTS OF COMPREHENSIVE INC

STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net income, pretax amount, attributable to parent	$ 3,081	$ 3,565	$ 2,695
Income tax (expense) benefit	(219)	(490)	(556)
Net income, after tax amount, attributable to parent	2,862	3,075	2,139
Other comprehensive income (loss):
Pension and other postretirement benefits, pretax amount, attributable to parent	18	(39)	3
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(16)	8	(6)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	(31)	(3)
Total other comprehensive income, pretax amount, attributable to parent	2	41	235
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(18)	(10)	(61)
Total other comprehensive income, net of tax amount, attributable to parent	(16)	31	174
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	3,082	3,605	2,929
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(237)	(500)	(617)
Comprehensive income, after preferred dividends of subsidiary	2,845	3,105	2,312
SDG&E
Net income, pretax amount, attributable to parent	1,044	910	1,097
Income tax (expense) benefit	(153)	26	(182)
Net income, after tax amount, attributable to parent	891	936	915
Other comprehensive income (loss):
Pension and other postretirement benefits, pretax amount, attributable to parent	(3)	(2)	4
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(1)	1	(1)
Pension and other postretirement benefits, net of tax amount, attributable to parent	(4)	(1)	3
Total other comprehensive income, pretax amount, attributable to parent	(3)	(2)	4
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(1)	1	(1)
Total other comprehensive income, net of tax amount, attributable to parent	(4)	(1)	3
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	1,041	908	1,101
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(154)	27	(183)
Comprehensive income, after preferred dividends of subsidiary	$ 887	$ 935	$ 918

BALANCE SHEETS - SDG&E

BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 1,565	$ 236
Accounts receivable – trade, net	1,983	2,151
Accounts receivable – other, net	397	561
Due from unconsolidated affiliates	13	31
Income taxes receivable, net	90	94
Inventories	559	482
Prepaid expenses	255	273
Regulatory assets	60	226
Fixed-price contracts and other derivatives	91	122
Greenhouse gas allowances	217	1,189
Other current assets	34	56
Total current assets	5,285	5,470
Other assets:
Regulatory assets	3,937	3,771
Greenhouse gas allowances	845	301
Nuclear decommissioning trusts	875	872
Right-of-use assets – operating leases	1,177	723
Wildfire fund	262	269
Other long-term assets	1,749	1,603
Total other assets	29,433	26,751
Property, plant and equipment:
Property, plant and equipment	80,397	72,495
Less accumulated depreciation and amortization	(18,960)	(17,535)
Property, plant and equipment, net	61,437	54,960
Total assets	96,155	87,181
Current liabilities:
Short-term debt	2,016	2,342
Accrued compensation and benefits	558	526
Regulatory liabilities	141	553
Current portion of long-term debt and finance leases	2,274	975
Greenhouse gas obligations	217	1,189
Total current liabilities	9,676	10,090
Long-term debt and finance leases	31,558	27,759
Deferred credits and other liabilities:
Regulatory liabilities	3,817	3,739
Greenhouse gas obligations	506	0
Pension obligation, net of plan assets	168	407
Deferred income taxes	5,845	5,254
Asset retirement obligations	3,737	3,642
Deferred credits and other	2,708	2,329
Total deferred credits and other liabilities	17,133	15,678
Commitments and contingencies
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock	13,520	12,204
Retained earnings	16,979	15,732
Accumulated other comprehensive income (loss)	(166)	(150)
Total shareholders’ equity	31,222	28,675
Total liabilities and shareholders’ equity	96,155	87,181
Related Party
Current assets:
Due from unconsolidated affiliates	13	31
Current liabilities:
Other current liabilities	0	5
Nonrelated Party
Current liabilities:
Other current liabilities	1,251	1,374
SDG&E
Current assets:
Cash and cash equivalents	0	50
Accounts receivable – trade, net	774	870
Accounts receivable – other, net	89	141
Income taxes receivable, net	27	236
Inventories	202	153
Prepaid expenses	139	165
Regulatory assets	16	19
Greenhouse gas allowances	27	158
Other current assets	27	31
Total current assets	1,301	1,823
Other assets:
Regulatory assets	2,024	1,968
Greenhouse gas allowances	272	202
Nuclear decommissioning trusts	875	872
Right-of-use assets – operating leases	795	368
Wildfire fund	262	269
Other long-term assets	133	134
Total other assets	4,361	3,813
Property, plant and equipment:
Property, plant and equipment	33,162	30,918
Less accumulated depreciation and amortization	(8,051)	(7,369)
Property, plant and equipment, net	25,111	23,549
Total assets	30,773	29,185
Current liabilities:
Short-term debt	417	0
Accounts payable	742	808
Interest payable	84	81
Accrued compensation and benefits	175	145
Accrued franchise fees	54	112
Regulatory liabilities	75	447
Current portion of long-term debt and finance leases	42	441
Greenhouse gas obligations	27	158
Asset retirement obligations	97	116
Total current liabilities	1,987	2,597
Long-term debt and finance leases	10,018	9,453
Deferred credits and other liabilities:
Regulatory liabilities	2,701	2,534
Greenhouse gas obligations	62	0
Pension obligation, net of plan assets	28	79
Deferred income taxes	3,211	2,873
Asset retirement obligations	803	778
Deferred credits and other	1,399	969
Total deferred credits and other liabilities	8,204	7,233
Commitments and contingencies
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	0	0
Common stock	1,660	1,660
Retained earnings	8,916	8,250
Accumulated other comprehensive income (loss)	(12)	(8)
Total shareholders’ equity	10,564	9,902
Total liabilities and shareholders’ equity	30,773	29,185
SDG&E | Related Party
Current liabilities:
Other current liabilities	59	73
SDG&E | Nonrelated Party
Current liabilities:
Other current liabilities	$ 215	$ 216

BALANCE SHEETS - SDG&E (Parenth

BALANCE SHEETS - SDG&E (Parentheticals) - shares	Dec. 31, 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)	650,629,876	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

STATEMENTS OF CASH FLOWS - SDG&

STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 3,500	$ 3,618	$ 2,285
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	2,437	2,227	2,019
Deferred income taxes and investment tax credits	(20)	249	392
Bad debt expense	209	458	122
Other	20	(14)	56
Net change in working capital components:
Accounts receivable	118	168	(976)
Due to/from unconsolidated affiliates, net	30	26	(31)
Income taxes receivable/payable, net	(49)	142	(29)
Inventories	(74)	(80)	(17)
Other current assets	(30)	11	(1,608)
Accounts payable	(131)	(270)	430
Regulatory balancing accounts, net	(456)	260	36
Other current liabilities	142	1,270	228
Changes in other noncurrent assets and liabilities, net	(150)	(594)	(564)
Net cash provided by operating activities	4,907	6,218	1,142
Net cash used in investing activities
Expenditures for property, plant and equipment	(8,215)	(8,397)	(5,357)
Purchases of nuclear decommissioning and other trust assets	(889)	(610)	(700)
Proceeds from sales of nuclear decommissioning and other trust assets	942	661	762
Other	23	12	6
Net cash used in investing activities	(9,118)	(8,716)	(5,039)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,499)	(1,483)	(1,430)
Issuances of debt (maturities greater than 90 days)	8,674	7,669	9,984
Payments on debt (maturities greater than 90 days) and finance leases	(3,339)	(6,294)	(4,510)
(Decrease) increase in short-term debt, net	(557)	552	(1,266)
Other	(56)	(85)	(35)
Net cash provided by financing activities	5,424	2,419	3,779
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	1,200	(73)	(119)
Cash, cash equivalents and restricted cash, January 1	389	462	581
Cash, cash equivalents and restricted cash, December 31	1,589	389	462
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Interest payments, net of amounts capitalized	1,205	1,172	1,014
Income tax payments, net of refunds	289	197	284
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Accrued capital expenditures for PP&E	1,181	1,052	590
Increase in finance lease obligations capitalized to PP&E	41	57	57
Increase in ARO capitalized to PP&E	1	33	91
SDG&E
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	891	936	915
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,223	1,098	982
Deferred income taxes and investment tax credits	169	135	93
Bad debt expense	55	112	46
Other	(14)	(35)	(34)
Net change in working capital components:
Accounts receivable	92	(213)	(163)
Due to/from unconsolidated affiliates, net	(14)	(62)	38
Income taxes receivable/payable, net	209	(236)	9
Inventories	(49)	(19)	(11)
Other current assets	(21)	(17)	(80)
Accounts payable	(32)	31	153
Regulatory balancing accounts, net	(429)	571	(10)
Other current liabilities	(21)	129	62
Changes in other noncurrent assets and liabilities, net	14	(494)	(271)
Net cash provided by operating activities	2,073	1,936	1,729
Net cash used in investing activities
Expenditures for property, plant and equipment	(2,522)	(2,540)	(2,473)
Purchases of nuclear decommissioning and other trust assets	(826)	(532)	(586)
Proceeds from sales of nuclear decommissioning and other trust assets	874	592	639
Other	13	8	8
Net cash used in investing activities	(2,461)	(2,472)	(2,412)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(225)	(100)	(100)
Issuances of debt (maturities greater than 90 days)	594	1,389	1,395
Payments on debt (maturities greater than 90 days) and finance leases	(442)	(490)	(425)
(Decrease) increase in short-term debt, net	417	(205)	(196)
Debt issuance costs	(6)	(13)	(9)
Other	0	(2)	0
Net cash provided by financing activities	338	579	665
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	(50)	43	(18)
Cash, cash equivalents and restricted cash, January 1	50	7	25
Cash, cash equivalents and restricted cash, December 31	0	50	7
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Interest payments, net of amounts capitalized	514	472	431
Income tax payments, net of refunds	(225)	76	79
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Accrued capital expenditures for PP&E	230	264	231
Increase in finance lease obligations capitalized to PP&E	14	17	16
Increase in ARO capitalized to PP&E	$ 24	$ 29	$ 15

STATEMENTS OF CHANGES IN SHAREH

STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E - USD ($) $ in Millions	Total	Sempra shareholders' equity	Retained earnings	Accumulated other comprehensive income (loss)	SDG&E	SDG&E Sempra shareholders' equity	SDG&E Common stock	SDG&E Retained earnings	SDG&E Accumulated other comprehensive income (loss)
Beginning balance at Dec. 31, 2021				$ (318)		$ 8,249	$ 1,660	$ 6,599	$ (10)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 2,285	$ 2,139	$ 2,139		$ 915	915		915
Other comprehensive income (loss)	228	174		174		3			3
Common stock dividends	(1,441)	(1,441)	(1,441)			(100)		(100)
Ending balance at Dec. 31, 2022				(135)		9,067	1,660	7,414	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,618	3,075	3,075		936	936		936
Other comprehensive income (loss)	3	31		31		(1)			(1)
Common stock dividends	(1,499)	(1,499)	(1,499)			(100)		(100)
Ending balance at Dec. 31, 2023	28,675			(150)	9,902	9,902	1,660	8,250	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,500	2,862	2,862		891	891		891
Other comprehensive income (loss)	(5)	(16)		(16)		(4)			(4)
Common stock dividends	(1,570)	$ (1,570)	$ (1,570)			(225)		(225)
Ending balance at Dec. 31, 2024	$ 31,222			$ (166)	$ 10,564	$ 10,564	$ 1,660	$ 8,916	$ (12)

STATEMENTS OF CHANGES IN SHAR_2

STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Dividends declared per share of common stock (in dollars per share)	$ 2.48	$ 2.38	$ 2.29
SDG&E
Dividends declared per share of common stock (in dollars per share)	$ 1.93	$ 0.86	$ 0.86

STATEMENTS OF OPERATIONS - SCG

STATEMENTS OF OPERATIONS - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating expenses:
Aliso Canyon litigation and regulatory matters	$ 0	$ 0	$ 259
Other income (expense), net	136	131	24
Interest income	61	89	75
Interest expense	(1,049)	(1,309)	(1,054)
Income before income taxes and equity earnings	2,110	2,627	1,343
Income tax (expense) benefit	(219)	(490)	(556)
Net income	3,500	3,618	2,285
Preferred dividends	(44)	(44)	(44)
Earnings attributable to common shares	2,817	3,030	2,094
SoCalGas
Operating Revenue	6,209	8,289	6,840
Operating expenses:
Cost of natural gas	959	3,264	2,233
Operation and maintenance	2,791	2,821	2,402
Aliso Canyon litigation and regulatory matters	0	0	259
Depreciation and amortization	910	839	761
Franchise fees and other taxes	273	278	247
Total operating expenses	4,933	7,202	5,902
Operating income (loss)	1,276	1,087	938
Other income (expense), net	25	(4)	(8)
Interest income	9	9	6
Interest expense	(323)	(285)	(198)
Income before income taxes and equity earnings	987	807	738
Income tax (expense) benefit	(31)	5	(138)
Net income	956	812	600
Preferred dividends	(1)	(1)	(1)
Earnings attributable to common shares	$ 955	$ 811	$ 599

STATEMENTS OF COMPREHENSIVE I_2

STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net income, pretax amount, attributable to parent	$ 3,081	$ 3,565	$ 2,695
Income tax expense	(219)	(490)	(556)
Net income, after tax amount, attributable to parent	2,862	3,075	2,139
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent	14	57	221
Financial instruments, income tax (expense) benefit, attributable to parent	(2)	(18)	(55)
Financial instruments, net of tax amount, attributable to parent	12	39	166
Pension and other postretirement benefits, pretax amount, attributable to parent	18	(39)	3
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(16)	8	(6)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	(31)	(3)
Total other comprehensive income, pretax amount, attributable to parent	2	41	235
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(18)	(10)	(61)
Total other comprehensive income, net of tax amount, attributable to parent	(16)	31	174
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	3,082	3,605	2,929
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(237)	(500)	(617)
Comprehensive income, after preferred dividends of subsidiary	2,845	3,105	2,312
SoCalGas
Net income, pretax amount, attributable to parent	987	807	738
Income tax expense	(31)	5	(138)
Net income, after tax amount, attributable to parent	956	812	600
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent	1	1	1
Financial instruments, income tax (expense) benefit, attributable to parent	0	0	0
Financial instruments, net of tax amount, attributable to parent	1	1	1
Pension and other postretirement benefits, pretax amount, attributable to parent	(4)		8
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(1)		(2)
Pension and other postretirement benefits, net of tax amount, attributable to parent	(5)		6
Total other comprehensive income, pretax amount, attributable to parent	(3)	1	9
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(1)	0	(2)
Total other comprehensive income, net of tax amount, attributable to parent	(4)	1	7
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	984	808	747
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(32)	5	(140)
Comprehensive income, after preferred dividends of subsidiary	$ 952	$ 813	$ 607

BALANCE SHEETS - SCG

BALANCE SHEETS - SCG - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 1,565	$ 236
Accounts receivable – trade, net	1,983	2,151
Accounts receivable – other, net	397	561
Due from unconsolidated affiliates	13	31
Inventories	559	482
Regulatory assets	60	226
Greenhouse gas allowances	217	1,189
Other current assets	34	56
Total current assets	5,285	5,470
Other assets:
Regulatory assets	3,937	3,771
Greenhouse gas allowances	845	301
Right-of-use assets – operating leases	1,177	723
Other long-term assets	1,749	1,603
Total other assets	29,433	26,751
Property, plant and equipment:
Property, plant and equipment	80,397	72,495
Less accumulated depreciation and amortization	(18,960)	(17,535)
Property, plant and equipment, net	61,437	54,960
Total assets	96,155	87,181
Current liabilities:
Short-term debt	2,016	2,342
Accounts payable – trade	2,238	2,211
Accounts payable – other	208	224
Accrued compensation and benefits	558	526
Regulatory liabilities	141	553
Current portion of long-term debt and finance leases	2,274	975
Greenhouse gas obligations	217	1,189
Total current liabilities	9,676	10,090
Long-term debt and finance leases	31,558	27,759
Deferred credits and other liabilities:
Regulatory liabilities	3,817	3,739
Greenhouse gas obligations	506	0
Pension and other postretirement benefit plan obligations, net of plan assets	168	407
Deferred income taxes	5,845	5,254
Asset retirement obligations	3,737	3,642
Deferred credits and other	2,708	2,329
Total deferred credits and other liabilities	17,133	15,678
Commitments and contingencies
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock	13,520	12,204
Retained earnings	16,979	15,732
Accumulated other comprehensive income (loss)	(166)	(150)
Total shareholders’ equity	31,222	28,675
Total liabilities and shareholders’ equity	96,155	87,181
Related Party
Current assets:
Due from unconsolidated affiliates	13	31
Current liabilities:
Other current liabilities	0	5
Nonrelated Party
Current liabilities:
Other current liabilities	1,251	1,374
SoCalGas
Current assets:
Cash and cash equivalents	12	2
Accounts receivable – trade, net	932	985
Accounts receivable – other, net	71	102
Due from unconsolidated affiliates	16	22
Inventories	287	277
Regulatory assets	42	204
Greenhouse gas allowances	176	950
Other current assets	71	100
Total current assets	1,607	2,642
Other assets:
Regulatory assets	1,844	1,715
Greenhouse gas allowances	526	62
Right-of-use assets – operating leases	18	29
Other long-term assets	609	645
Total other assets	2,997	2,451
Property, plant and equipment:
Property, plant and equipment	29,084	27,025
Less accumulated depreciation and amortization	(8,330)	(7,852)
Property, plant and equipment, net	20,754	19,173
Total assets	25,358	24,266
Current liabilities:
Short-term debt	1,037	946
Accounts payable – trade	752	811
Accounts payable – other	158	184
Accrued compensation and benefits	245	213
Regulatory liabilities	64	103
Current portion of long-term debt and finance leases	373	523
Greenhouse gas obligations	176	950
Asset retirement obligations	91	73
Total current liabilities	3,385	4,407
Long-term debt and finance leases	7,031	6,288
Deferred credits and other liabilities:
Regulatory liabilities	1,115	1,202
Greenhouse gas obligations	410	0
Pension and other postretirement benefit plan obligations, net of plan assets	45	231
Deferred income taxes	2,005	1,586
Asset retirement obligations	2,839	2,774
Deferred credits and other	367	368
Total deferred credits and other liabilities	6,781	6,161
Commitments and contingencies
Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	22	22
Common stock	2,316	2,316
Retained earnings	5,850	5,095
Accumulated other comprehensive income (loss)	(27)	(23)
Total shareholders’ equity	8,161	7,410
Total liabilities and shareholders’ equity	25,358	24,266
SoCalGas | Related Party
Current assets:
Due from unconsolidated affiliates	16	22
Current liabilities:
Other current liabilities	38	38
SoCalGas | Nonrelated Party
Current liabilities:
Other current liabilities	$ 451	$ 566

BALANCE SHEETS - SCG (Parenthet

BALANCE SHEETS - SCG (Parentheticals) - shares	Dec. 31, 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)	650,629,876	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

STATEMENTS OF CASH FLOWS - SCG

STATEMENTS OF CASH FLOWS - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 3,500	$ 3,618	$ 2,285
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	2,437	2,227	2,019
Deferred income taxes and investment tax credits	(20)	249	392
Bad debt expense	209	458	122
Other	20	(14)	56
Net change in working capital components:
Accounts receivable	118	168	(976)
Due to/from unconsolidated affiliates, net	30	26	(31)
Income taxes receivable/payable, net	(49)	142	(29)
Inventories	(74)	(80)	(17)
Other current assets	(30)	11	(1,608)
Accounts payable	(131)	(270)	430
Regulatory balancing accounts, net	(456)	260	36
Reserve for Aliso Canyon costs	(12)	(98)	(1,851)
Other current liabilities	142	1,270	228
Insurance receivable for Aliso Canyon costs	0	0	360
Changes in other noncurrent assets and liabilities, net	(150)	(594)	(564)
Net cash provided by operating activities	4,907	6,218	1,142
Net cash used in investing activities
Expenditures for property, plant and equipment	(8,215)	(8,397)	(5,357)
Net cash used in investing activities	(9,118)	(8,716)	(5,039)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,499)	(1,483)	(1,430)
Preferred dividends paid	(44)	(44)	(44)
Issuances of debt (maturities greater than 90 days)	8,674	7,669	9,984
Payments on debt (maturities greater than 90 days) and finance leases	(3,339)	(6,294)	(4,510)
(Decrease) increase in short-term debt, net	(557)	552	(1,266)
Net cash provided by financing activities	5,424	2,419	3,779
Increase (decrease) in cash, cash equivalents and restricted cash	1,200	(73)	(119)
Cash, cash equivalents and restricted cash, January 1	389	462	581
Cash, cash equivalents and restricted cash, December 31	1,589	389	462
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Interest payments, net of amounts capitalized	1,205	1,172	1,014
Income tax payments, net of refunds	289	197	284
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Accrued capital expenditures for PP&E	1,181	1,052	590
Capital expenditures reclassed from assets to PP&E	53	18	5
Increase in finance lease obligations capitalized to PP&E	41	57	57
Increase in ARO capitalized to PP&E	1	33	91
SoCalGas
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	956	812	600
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	910	839	761
Deferred income taxes and investment tax credits	28	12	146
Bad debt expense	97	294	70
Other	(6)	(12)	(12)
Net change in working capital components:
Accounts receivable	(13)	207	(512)
Due to/from unconsolidated affiliates, net	6	57	(28)
Income taxes receivable/payable, net	13	(8)	23
Inventories	(10)	(118)	13
Other current assets	6	(1,053)	(139)
Accounts payable	(103)	(179)	191
Regulatory balancing accounts, net	(27)	(311)	46
Reserve for Aliso Canyon costs	(12)	(98)	(1,851)
Other current liabilities	46	1,047	185
Insurance receivable for Aliso Canyon costs	0	0	360
Changes in other noncurrent assets and liabilities, net	(100)	(100)	(307)
Net cash provided by operating activities	1,791	1,389	(454)
Net cash used in investing activities
Expenditures for property, plant and equipment	(2,231)	(2,020)	(1,993)
Net cash used in investing activities	(2,231)	(2,020)	(1,993)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(200)	(100)	0
Preferred dividends paid	(1)	(1)	(1)
Equity contribution from Sempra	0	0	650
Issuances of debt (maturities greater than 90 days)	1,794	997	2,094
Payments on debt (maturities greater than 90 days) and finance leases	(524)	(1,120)	(15)
(Decrease) increase in short-term debt, net	(609)	846	(285)
Debt issuance costs	(10)	(10)	(12)
Net cash provided by financing activities	450	612	2,431
Increase (decrease) in cash, cash equivalents and restricted cash	10	(19)	(16)
Cash, cash equivalents and restricted cash, January 1	2	21	37
Cash, cash equivalents and restricted cash, December 31	12	2	21
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Interest payments, net of amounts capitalized	299	279	173
Income tax payments, net of refunds	(9)	6	(31)
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Accrued capital expenditures for PP&E	308	290	245
Capital expenditures reclassed from assets to PP&E	50	0	0
Increase in finance lease obligations capitalized to PP&E	27	40	41
Increase in ARO capitalized to PP&E	$ (23)	$ 1	$ 63

STATEMENTS OF CHANGES IN SHAR_3

STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SCG - 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, 2021			$ (318)	$ 5,442	$ 22	$ 1,666	$ 3,785	$ (31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 2,285	$ 2,139		600			600
Other comprehensive income (loss)	228		174	7				7
Preferred dividends				(1)			(1)
Common stock dividends	(1,441)	(1,441)
Equity contributions from Sempra				650		650
Ending balance at Dec. 31, 2022			(135)	6,698	22	2,316	4,384	(24)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,618	3,075		812			812
Other comprehensive income (loss)	3		31	1				1
Preferred dividends				(1)			(1)
Common stock dividends	(1,499)	(1,499)		(100)			(100)
Ending balance at Dec. 31, 2023	28,675		(150)	7,410	22	2,316	5,095	(23)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,500	2,862		956			956
Other comprehensive income (loss)	(5)		(16)	(4)				(4)
Preferred dividends				(1)			(1)
Common stock dividends	(1,570)	$ (1,570)		(200)			(200)
Ending balance at Dec. 31, 2024	$ 31,222		$ (166)	$ 8,161	$ 22	$ 2,316	$ 5,850	$ (27)

STATEMENTS OF CHANGES IN SHAR_4

STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SCG (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Dividends declared per share of common stock (in dollars per share)	$ 2.48	$ 2.38	$ 2.29
SoCalGas
Dividends declared per share of preferred stock (in dollars per share)	1.50	1.50	$ 1.50
Dividends declared per share of common stock (in dollars per share)	$ 2.19	$ 1.10

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Significant Accounting Policies And Other Financial Data	SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Consolidated Financial Statements include the accounts of Sempra, 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 operating and reportable segments, which we describe in Note 16. 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 operating and 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 operating and 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 Sempra’s consolidated financial statements. Use of Estimates in the Preparation of the Financial Statements We have prepared our financial statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates. Subsequent Events We evaluated events and transactions that occurred after December 31, 2024 through the date the financial statements were issued, and in the opinion of management, the accompanying financial statements reflect all adjustments and disclosures necessary for a fair presentation. REGULATED OPERATIONS SDG&E’s and SoCalGas’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from customers, the excess would be refunded to customers, generally by reducing future rates. Regulatory assets and liabilities may also arise from other transactions such as unrealized losses and/or gains on fixed-price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, the FERC, requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and, in the case of Oncor, certain cities and are subject to regulatory rate-setting processes and earnings oversight. Oncor and Sharyland Utilities prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. Sempra Infrastructure’s natural gas distribution utility, Ecogas, also applies U.S. GAAP provisions governing rate-regulated operations, including the same evaluation of probability of recovery of regulatory assets described above. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily NDT and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, short-term investments, and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and, until December 31, 2022, fixed-price electricity positions, at SDG&E and the Support Agreement at Sempra Infrastructure. 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 December 31, 2024 and 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 $1,138 million and $1,166 million at December 31, 2024 and 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 15. 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 5 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 $15,400 million and $14,266 million at December 31, 2024 and 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 $1,149 million and $1,008 million at December 31, 2024 and 2023, respectively. 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 10). 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 $1,758 million and $1,580 million of assets at December 31, 2024 and 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 $1,080 million and $1,029 million of liabilities at December 31, 2024 and 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 $6,419 million and $3,927 million of assets at December 31, 2024 and 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 $1,584 million and $600 million of liabilities at December 31, 2024 and 2023, respectively, consisting primarily of long-term debt and accounts payable attributable to Port Arthur LNG for which creditors do not have recourse to the general credit of Sempra. CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase. Restricted cash includes: ▪ certain funds at Port Arthur LNG for which withdrawals and usage are dictated by its debt agreements ▪ funds held as collateral in lieu of a customer’s letters of credit associated with its LNG storage and regasification agreement ▪ funds denominated in U.S. dollars and Mexican pesos to pay for rights-of-way and other costs pursuant to trust agreements related to pipeline projects ▪ funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) December 31, 2024 2023 Sempra: Cash and cash equivalents $ 1,565 $ 236 Restricted cash, current 21 49 Restricted cash, noncurrent 3 104 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 1,589 $ 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. After considering the past-due status of receivables, payment history and other customer-specific information, in 2024 and 2023, Sempra recorded a provision for expected credit losses of $53 million and $52 million, respectively, on a customer’s past due account balance. 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. 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. 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 2022 Sempra: Allowances for credit losses at January 1 $ 533 $ 181 $ 136 Provisions for expected credit losses 203 468 123 Write-offs (222) (116) (78) Allowances for credit losses at December 31 $ 514 $ 533 $ 181 SDG&E: Allowances for credit losses at January 1 $ 144 $ 78 $ 66 Provisions for expected credit losses 52 115 54 Write-offs (82) (49) (42) Allowances for credit losses at December 31 $ 114 $ 144 $ 78 SoCalGas: Allowances for credit losses at January 1 $ 331 $ 98 $ 69 Provisions for expected credit losses 94 300 65 Write-offs (140) (67) (36) Allowances for credit losses at December 31 $ 285 $ 331 $ 98 Allowances for credit losses related to trade receivables and other receivables are included in the Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) December 31, 2024 2023 Sempra: Accounts receivable – trade, net $ 447 $ 480 Accounts receivable – other, net 53 52 Other long-term assets 14 1 Total allowances for credit losses $ 514 $ 533 SDG&E: Accounts receivable – trade, net $ 81 $ 116 Accounts receivable – other, net 25 27 Other long-term assets 8 1 Total allowances for credit losses $ 114 $ 144 SoCalGas: Accounts receivable – trade, net $ 251 $ 306 Accounts receivable – other, net 28 25 Other long-term assets 6 — Total allowances for credit losses $ 285 $ 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 December 31, 2024 and 2023, $5 million and $6 million, respectively, of expected credit losses are included in Other Long-Term Assets on Sempra’s 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 December 31, 2024 and 2023, $5 million of expected credit losses are included in Deferred Credits and Other on Sempra’s Consolidated Balance Sheets. CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by the respective credit departments at each of the Registrants and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a regular basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: ▪ prospective counterparties’ financial condition (including credit ratings) ▪ collateral requirements ▪ the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty ▪ downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance in our allowances for credit losses. 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) December 31, 2024 2023 Sempra: Tax sharing agreement with Oncor Holdings $ 8 $ 25 Various affiliates 5 6 Total due from unconsolidated affiliates – current $ 13 $ 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 (19) (17) 5.5% Note due January 19, 2028 (48) — 5.5% Note due July 18, 2028 (41) — TAG Norte – 5.74% Note due December 17, 2029 (1) (209) (198) Total due to unconsolidated affiliates – noncurrent $ (352) $ (307) SDG&E: Sempra $ (42) $ (44) SoCalGas (14) (21) Various affiliates (3) (8) Total due to unconsolidated affiliates – current $ (59) $ (73) Income taxes due from Sempra (2) $ 38 $ 246 SoCalGas: SDG&E $ 14 $ 21 Various affiliates 2 1 Total due from unconsolidated affiliates – current $ 16 $ 22 Sempra $ (38) $ (38) Total due to unconsolidated affiliates – current $ (38) $ (38) Income taxes due (to) from Sempra (2) $ (6) $ 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. The following table summarizes income statement information from unconsolidated affiliates. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Revenues $ 40 $ 44 $ 41 Interest income — — 16 Interest expense 16 15 15 SDG&E: Revenues $ 23 $ 21 $ 16 Cost of sales 146 113 92 SoCalGas: Revenues $ 169 $ 124 $ 100 Cost of sales (1) (5) 35 (9) (1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates. Sempra, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Also, from time-to-time, SDG&E and SoCalGas may make short-term advances of surplus cash to Sempra at interest rates based on the federal funds effective rate plus a margin of 13 to 20 bps, depending on the loan balance. Such amounts are eliminated in consolidation at Sempra. SDG&E and SoCalGas charge one another, as well as other Sempra affiliates, for shared asset depreciation. SoCalGas and SDG&E record revenues and the affiliates record corresponding amounts to O&M. Such amounts are eliminated in consolidation at Sempra. SDG&E has a 20-year contract that commenced in June 2015 for up to 155 MW of renewable power supplied from the ESJ wind power generation facility, a consolidated subsidiary of Sempra. A second 20-year contract between SDG&E and ESJ for up to 108 MW of renewable power supplied from the same facility commenced in January 2022. Such amounts are eliminated in consolidation at Sempra. The natural gas supply for SDG&E’s and SoCalGas’ core natural gas customers is purchased by SoCalGas as a combined procurement portfolio managed by SoCalGas. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service; therefore, SoCalGas records revenues net of costs in cost of sales. Such amounts are eliminated in consolidation at Sempra. SoCalGas provides natural gas transportation and storage services to SDG&E and charges SDG&E for such services monthly. SoCalGas records revenues and SDG&E records a corresponding amount to cost of sales. Such amounts are eliminated in consolidation at Sempra. SoCalGas provides transportation services to Ecogas. SoCalGas records revenues and Ecogas records a corresponding amount to cost of sales. Such amounts are eliminated in consolidation at Sempra. SoCalGas and Sempra Infrastructure may buy and sell natural gas from and to each other in open market transactions to help satisfy supply needs. SoCalGas records revenues and costs in cost of sales. Sempra Infrastructure records revenues and costs in revenues. Such amounts are eliminated in consolidation at Sempra. Sempra Infrastructure has agreements with Cameron LNG JV to provide certain business services and project development services related to the Cameron LNG Phase 2 project. Sempra Infrastructure provides maintenance and administrative services to TAG Pipelines. Additionally, Sempra Infrastructure subleases office space for personnel to TAG Pipelines and TAG Norte. Sempra provides guarantees related to Cameron LNG JV’s SDSRA and CFIN’s Support Agreement. We discuss these guarantees in Note 5. INVENTORIES SDG&E and SoCalGas value natural gas inventory using the last-in first-out method. Sempra Infrastructure values natural gas inventory at the lower of average cost or net realizable value. We record natural gas to inventory when injected and then to expense when the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Sempra Infrastructure values LNG inventory at the lower of average cost or net realizable value. We record LNG to inventory when delivered to our terminals and then to expense when transported from our terminals. SDG&E, SoCalGas and Sempra Infrastructure generally value materials and supplies at the lower of average cost or net realizable value. We record materials and supplies to inventory when purchased and then to expense or capitalized to PP&E, as appropriate, when used. The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Natural gas $ 163 $ 174 $ 1 $ 1 $ 148 $ 155 LNG 27 9 — — — — Materials and supplies 369 299 201 152 139 122 Total $ 559 $ 482 $ 202 $ 153 $ 287 $ 277 GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS SDG&E, SoCalGas and Sempra Infrastructure are required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas consumption. SDG&E and SoCalGas receive allocations of GHG allowances on behalf of their customers at no cost and purchase any additional allowances required. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Infrastructure records the cost of GHG obligations in cost of sales. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. 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. Investor-owned gas distribution utilities such as SoCalGas are not covered by this legislation. The issues addressed include wildfire mitigation, cost recovery standards and requirements, a wildfire fund, a cap on liability, and the establishment of a wildfire safety board. The Wildfire Legislation established a revised legal standard for the recovery of wildfire costs (Revised Prudent Manager Standard) and established a fund (the Wildfire Fund) designed to provide liquidity to SDG&E, PG&E and Edison to pay IOU wildfire-related claims in the event that the governmental agency responsible for determining causation determines the applicable IOU’s equipment caused the ignition of a wildfire, primary insurance coverage is exceeded and certain other conditions are satisfied. A primary purpose of the Wildfire Fund is to pool resources provided by shareholders and ratepayers of the IOUs and make those resources available to reimburse the IOUs for third-party wildfire claims incurred after July 12, 2019, the effective da

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 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. We adopted the standard on December 31, 2024 and revised our segment reporting disclosures in Note 16 on a retrospective basis. 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 annual reporting periods beginning after December 15, 2026, and interim periods within annual reporting periods 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	12 Months Ended
	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUES 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 Year ended December 31, 2024 By major service line: Utilities $ 11,008 $ 78 $ (23) $ 11,063 Energy-related businesses — 818 (63) 755 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 By market: Gas $ 6,858 $ 471 $ (21) $ 7,308 Electric 4,150 425 (65) 4,510 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 Utilities regulatory revenues 374 — — 374 Other revenues — 986 7 993 Total revenues $ 11,382 $ 1,882 $ (79) $ 13,185 Year ended December 31, 2023 By major service line: Utilities $ 13,686 $ 87 $ (19) $ 13,754 Energy-related businesses — 1,164 (70) 1,094 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 By market: Gas $ 8,949 $ 755 $ (17) $ 9,687 Electric 4,737 496 (72) 5,161 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 Utilities regulatory revenues 75 — — 75 Other revenues — 1,820 (23) 1,797 Total revenues $ 13,761 $ 3,071 $ (112) $ 16,720 Year ended December 31, 2022 By major service line: Utilities $ 11,944 $ 89 $ (15) $ 12,018 Energy-related businesses — 1,760 (56) 1,704 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 By market: Gas $ 7,267 $ 1,270 $ (12) $ 8,525 Electric 4,677 579 (59) 5,197 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 Utilities regulatory revenues 633 — — 633 Other revenues — 70 14 84 Total revenues $ 12,577 $ 1,919 $ (57) $ 14,439 DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 By major service line: Revenues from contracts with customers – Utilities $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 By market: Gas $ 878 $ 1,204 $ 899 $ 6,134 $ 7,857 $ 6,459 Electric 4,164 4,750 4,687 — — — Revenues from contracts with customers $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 Revenues from contracts with customers $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 Utilities regulatory revenues 299 (357) 252 75 432 381 Total revenues $ 5,341 $ 5,597 $ 5,838 $ 6,209 $ 8,289 $ 6,840 REVENUES FROM CONTRACTS WITH CUSTOMERS Revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity or service is provided to customers and invoices are issued for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of respective performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ ability to collect from customers, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: ▪ The transmission, distribution and storage of natural gas at: ◦ SDG&E ◦ SoCalGas ◦ Sempra’s Ecogas ▪ The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue from customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings and collections, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. SDG&E and SoCalGas recognize revenues from the sale of allocated California GHG emission allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and SDG&E and SoCalGas have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Revenues at Sempra Infrastructure typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency impacts and the actual quantity of commodity transported. Sempra Infrastructure develops, invests in and operates solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated and delivered. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities as the power is delivered at the interconnection point. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 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 December 31, 2024. REMAINING PERFORMANCE OBLIGATIONS (Dollars in millions) Sempra (1) SDG&E 2025 $ 403 $ 4 2026 284 4 2027 285 4 2028 239 4 2029 211 4 Thereafter 2,101 52 Total revenues to be recognized $ 3,523 $ 72 (1) Excludes intercompany transactions. Contract Liabilities from Revenues from Contracts with Customers From time to time, we receive payments in advance of satisfying the performance obligations associated with customer contracts. We defer such revenues as contract liabilities and recognize them in earnings as the performance obligations are satisfied. Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in 2024, 2023 or 2022. CONTRACT LIABILITIES (Dollars in millions) 2024 2023 2022 Sempra: Contract liabilities at January 1 $ (198) $ (252) (278) Revenue from performance obligations satisfied during reporting period 11 14 131 Payments received in advance (7) (21) (105) Contract modification (2) 61 — Contract liabilities at December 31 (1) $ (196) $ (198) $ (252) SDG&E: Contract liabilities at January 1 $ (75) $ (79) $ (83) Revenue from performance obligations satisfied during reporting period 3 4 4 Contract liabilities at December 31 (2) $ (72) $ (75) $ (79) (1) Balances at December 31, 2024 and 2023 include $105 and $5, respectively, in Other Current Liabilities and $91 and $193, respectively, in Deferred Credits and Other. (2) Balances at December 31, 2024 and 2023 include $4 and $3, respectively, in Other Current Liabilities and $68 and $72, respectively, in Deferred Credits and Other. Sempra Infrastructure previously 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. In December 2024, Sempra Infrastructure and the customer agreed to modify their LNG storage and regasification agreement by reducing the remaining term of the agreement from approximately three years to one year, now expiring in December 2025. As a result of the modification, Sempra Infrastructure will recognize approximately $107 million, which the customer paid in advance, in revenue over the remaining one-year term. The net effect to our contract liabilities is reflected in “contract modification” in the table above. As we discuss in Note 1 in “Property, Plant and Equipment,” Sempra Infrastructure and the CFE have agreed to an amendment to their transportation services agreement for the Guaymas-El Oro segment of the Sonora pipeline. Sempra Infrastructure determined that the amended transportation services agreement met the definition of a lease. In December 2023, Sempra reclassified $61 million from contract liabilities to other noncurrent liabilities, both within Deferred Credits and Other on Sempra’s Consolidated Balance Sheet. 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 Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2024 2023 Sempra: Accounts receivable – trade, net (1) $ 1,787 $ 1,951 Accounts receivable – other, net 12 15 Due from unconsolidated affiliates – current (2) 4 4 Other long-term assets (3) 18 — Total $ 1,821 $ 1,970 SDG&E: Accounts receivable – trade, net (1) $ 774 $ 870 Accounts receivable – other, net 11 13 Due from unconsolidated affiliates – current (2) 6 6 Other long-term assets (3) 4 — Total $ 795 $ 889 SoCalGas: Accounts receivable – trade, net $ 932 $ 985 Accounts receivable – other, net 1 2 Other long-term assets (3) 14 — Total $ 947 $ 987 (1) At December 31, 2024 and 2023, includes $144 and $148, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues. (2) Amount is presented net of amounts due to unconsolidated affiliates on the 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. REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled Revenues. As we discuss above, the regulatory framework requires SDG&E and SoCalGas to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive Mechanisms. SoCalGas is subject to the GCIM and is eligible for financial awards or subject to financial penalties depending on its performance in relation to specific benchmarks. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize SDG&E and SoCalGas to collect, or in the case of CPUC programmatic activities, to apply for additional, revenue requirements beyond base rates from customers for certain operating and capital related costs (depreciation, taxes and return on rate base), including for: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, environmental compliance, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity or service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded in a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met when the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund of amounts accumulated for authorized programs, including limitations on the program’s total cost, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in delays or disallowances of recovery from customers. We discuss balancing accounts and their effects further in Note 4. Other Revenues Sempra Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and refined products terminals. We discuss the recognition of lease income in Note 15. Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes. Sempra Infrastructure also recognizes other revenues associated with derivatives related to the sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of these derivatives.

REGULATORY MATTERS

REGULATORY MATTERS	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until 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) AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Fixed-price contracts and other derivatives $ 53 $ 215 $ 11 $ 14 $ 42 $ 201 Deferred income taxes recoverable in rates 1,689 1,142 802 626 817 430 Pension and PBOP plan obligations (458) (212) (2) 48 (456) (260) Employee benefit costs 19 24 3 3 16 21 Removal obligations (3,295) (3,082) (2,676) (2,468) (619) (614) Environmental costs 149 139 115 105 34 34 Sunrise Powerlink fire mitigation 124 124 124 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (313) (233) (313) (233) — — Commodity – gas, including transportation (47) (259) 86 52 (133) (311) Safety and reliability 820 959 227 207 593 752 Public purpose programs (439) (273) (219) (144) (220) (129) 2024 GRC retroactive impacts 631 — 277 — 354 — Wildfire mitigation plan 808 685 808 685 — — Liability insurance premium (24) 113 (15) 90 (9) 23 Other balancing accounts 158 373 (51) (152) 209 525 Other regulatory assets (liabilities), net (2) 164 (10) 87 49 79 (58) Total $ 39 $ (295) $ (736) $ (994) $ 707 $ 614 (1) At December 31, 2024 and 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $1,731 and $1,913, respectively, for SDG&E was $873 and $950, respectively, and for SoCalGas was $858 and $963, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. Regulatory Assets Not Earning a Return ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. The related amounts are recovered in rates once these contracts are settled, generally within four years. ▪ Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Infrastructure expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include excess deferred income taxes resulting from statutory income tax rate changes and certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 7. ▪ Regulatory assets/liabilities related to pension and PBOP plan obligations are offset by corresponding liabilities/assets. The assets are recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 45-year period. Regulatory Assets Earning a Return ▪ Over- and undercollected regulatory balancing accounts and other regulatory assets, net, reflect the difference between customer billings and recorded or CPUC-authorized amounts. Depreciation, taxes and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. The adopted revenue requirements in the 2024 GRC FD were placed into rates on February 1, 2025 and the incremental revenue requirements associated with the period from January 1, 2024 through January 31, 2025 are being recovered in rates over an 18-month period that began on February 1, 2025. SDG&E and SoCalGas periodically make requests to the CPUC to true up their revenue requirement for amounts accumulated in the regulatory balancing accounts and in other regulatory assets, net. The CPUC may impose various review procedures before authorizing recovery or refund of amounts accumulated for authorized programs, including limitations on the program’s total cost, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in delays or disallowances of recovery from customers. Amortization expense on certain regulatory assets for the years ended December 31, 2024, 2023 and 2022 was $14 million, $12 million and $11 million, respectively, at Sempra, $7 million, $6 million and $5 million, respectively, at SDG&E, and $7 million, $6 million and $6 million, respectively, at SoCalGas. CPUC GRC The CPUC uses GRCs to set revenues to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. In December 2024, the CPUC approved an FD in the 2024 GRC for SDG&E and SoCalGas that authorizes SDG&E’s and SoCalGas’ revenue requirements for 2024 and attrition year adjustments for 2025 through 2027, inclusively. The GRC FD adopts a 2024 revenue requirement of $2,699 million for SDG&E’s combined operations ($2,193 million for its electric operations and $506 million for its natural gas operations). SDG&E’s authorized 2024 combined revenue requirement represents an increase of $189 million (7.5%) over its authorized 2023 combined revenue requirement. In connection with SDG&E’s election to change its tax accounting method for gas repairs expenditures, the 2024 combined revenue requirement increase is net of $68 million of income tax benefits for 2023 and 2024 to be flowed through to customers. The GRC FD also specifies an increase in SDG&E’s 2025, 2026, and 2027 combined revenue requirements of $147 million (5.45%), $119 million (4.17%) and $122 million (4.11%), respectively, over the preceding year’s combined revenue requirement. The 2025, 2026 and 2027 revenue requirements will be updated to implement a previously authorized change in the cost of capital, which we describe below, that adjusted SDG&E’s rate of return to 7.45%. The GRC FD adopts a 2024 revenue requirement of $3,806 million for SoCalGas. SoCalGas’ authorized 2024 revenue requirement represents an increase of $324 million (9.3%) over its authorized 2023 revenue requirement. In connection with SoCalGas’ election to change its tax accounting method for gas repairs expenditures, the 2024 revenue requirement increase is net of $202 million of income tax benefits for 2023 and 2024 to be flowed through to customers. The GRC FD also specifies an increase in SoCalGas’ 2025, 2026, and 2027 revenue requirements of $190 million (5.00%), $116 million (2.91%) and $120 million (2.92%), respectively, over the preceding year’s revenue requirement. The 2025, 2026 and 2027 revenue requirements will be updated to implement a previously authorized change in the cost of capital, which we describe below, that adjusted SoCalGas’ rate of return to 7.49%. The GRC provides SDG&E and SoCalGas with numerous mechanisms to seek cost recovery of specified projects and programs. We expect that the requests for cost recovery of these projects and programs, which remain subject to CPUC approval, will result in additional amounts of authorized revenue requirement that are not included in the amounts described above. Since the GRC FD is effective retroactive to January 1, 2024, SDG&E and SoCalGas recorded the retroactive impacts in the fourth quarter of 2024. 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 and not addressed in the 2024 GRC FD. SDG&E expects to receive a proposed decision for its Track 2 request in the first half of 2025. Revenue requirements associated with the Track 2 request have been recorded in a regulatory account. In February 2024, the CPUC approved an interim cost recovery mechanism that permits 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 wildfire mitigation plan costs incurred in 2023. The GRC FD expanded the scope of the Track 3 filing to include review of SoCalGas’ and SDG&E’s Pipeline Safety Enhancement Plan costs incurred from 2015 to 2020, inclusively. CPUC COST OF CAPITAL A CPUC cost of capital proceeding every three years determines a utility’s authorized capital structure and authorized return on rate base. The CCM applies in the interim years and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered in each measurement period, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.00% for the measurement period. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application to have its cost of capital determined in lieu of the CCM in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. The CPUC-approved cost of capital for SDG&E and SoCalGas that became effective on January 1, 2020 remained in effect through December 31, 2022. The CPUC subsequently approved the 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. The CCM was triggered for SDG&E and SoCalGas for the measurement period ending September 30, 2023, and in December 2023, the CPUC approved updated authorized rates of return effective January 1, 2024. 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 an FD to modify the CCM. The FD updates the upward or downward adjustment to authorized ROE, if the CCM is triggered, from 50% to 20% of the change in the benchmark rate during the measurement period. The FD adopted 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. The following table summarizes the cost of capital for SDG&E and SoCalGas. The authorized weighting remained unchanged for each of the years presented. AUTHORIZED COST OF CAPITAL Authorized weighting 2022 2023 2024 2025 2022 2023 (1) 2024 2025 Return on rate base Weighted return on rate base SDG&E: Long-Term Debt 45.25 % 4.59 % 4.05 % 4.34 % 4.34 % 2.08 % 1.83 % 1.96 % 1.96 % Preferred Equity 2.75 6.22 6.22 6.22 6.22 0.17 0.17 0.17 0.17 Common Equity 52.00 10.20 9.95 10.65 10.23 5.30 5.17 5.54 5.32 100.00 % 7.55 % 7.18 % 7.67 % 7.45 % SoCalGas: Long-Term Debt 45.60 % 4.23 % 4.07 % 4.54 % 4.63 % 1.93 % 1.86 % 2.07 % 2.11 % Preferred Equity 2.40 6.00 6.00 6.00 6.00 0.14 0.14 0.14 0.14 Common Equity 52.00 10.05 9.80 10.50 10.08 5.23 5.10 5.46 5.24 100.00 % 7.30 % 7.10 % 7.67 % 7.49 % (1) Total weighted return on rate base for SDG&E does not sum due to rounding differences. 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. TO5 Settlement SDG&E’s authorized TO5 settlement provided for an ROE of 10.60%, consisting of a base ROE of 10.10% plus the California ISO adder. In December 2024, the FERC issued an order, which SDG&E has appealed, finding that SDG&E is not eligible for the California ISO adder and that the TO5 adder refund provision has been triggered, requiring SDG&E to refund customers the California ISO adder retroactively from June 1, 2019. As a result of the FERC order, SDG&E recorded a charge of $120 million ($89 million after tax) with $94 million in Electric Revenues and $26 million in Other Income, Net, on the SDG&E and Sempra Consolidated Statements of Operations in the year ended December 31, 2024. TO6 Filing 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, requested to be effective January 1, 2025, and 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% plus the California ISO adder, for a total ROE of 12.25%. In December 2024, the FERC accepted SDG&E’s TO6 filing but suspended the effective date to June 1, 2025 and disallowed the inclusion of the California ISO adder, which SDG&E has appealed. SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra’s and SDG&E’s Consolidated Statements of Operations. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to 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 an ISFSI and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In January 2025, the CPUC granted SDG&E authorization to access NDT funds of up to $66 million for forecasted 2025 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 10. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated December 31, 2024 Short-term investments, primarily cash equivalents $ 10 $ — $ — $ 10 Equity securities 78 223 (3) 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 67 1 (1) 67 Municipal bonds (2) 295 1 (9) 287 Other securities (3) 234 2 (8) 228 Total debt securities 596 4 (18) 582 Receivables (payables), net (15) — — (15) Total $ 669 $ 227 $ (21) $ 875 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 2025-2062. (3) Maturity dates are 2025-2072. The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Proceeds from sales $ 874 $ 592 $ 639 Gross realized gains 57 27 18 Gross realized losses 10 14 20 Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. ASSET RETIREMENT OBLIGATION The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $471 million at December 31, 2024 and is based on a cost study prepared in 2024, which is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $89 million in 2025, $57 million in 2026, $37 million in 2027, $25 million in 2028, $11 million in 2029, and $870 million thereafter. U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC. The ISFSI will operate until 2054, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018, which is pending approval. Additionally, in July 2024, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from August 2018 through December 2021, which is pending approval. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $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	12 Months Ended
	Dec. 31, 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 Consolidated Statements of Operations. Distributions received from equity method investees are classified in the 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. Our equity method investments include various domestic and foreign entities. Our domestic equity method investees are typically partnerships that are pass-through entities for income tax purposes and therefore they do not record income tax. Sempra’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense on the Consolidated Statements of Operations. Our foreign equity method investees are generally corporations whose operations are taxable on a standalone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax. See Note 7 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR. We provide the carrying values of our investments and earnings on these investments by segment in the following tables. EQUITY METHOD AND OTHER INVESTMENTS (1) (Dollars in millions) Percent ownership Investment balance December 31, 2024 2023 2024 2023 Sempra Texas Utilities: Oncor Holdings (2) 100 % 100 % $ 15,400 $ 14,266 Sempra Texas Utilities: Sharyland Holdings (3) 50 % 50 % $ 122 $ 114 Sempra Infrastructure: Cameron LNG JV (4) 50.2 50.2 1,149 1,008 IMG (5) 40 40 723 620 TAG Norte (6) 50 50 539 501 Segment totals 2,533 2,243 Parent and other – Other 1 1 Total $ 2,534 $ 2,244 (1) All amounts are before NCI, where applicable. (2) The carrying value of our equity method investment is $2,884 and $2,870 higher than the underlying equity in the net assets of the investee at December 31, 2024 and 2023, respectively, due to $2,868 of equity method goodwill and $69 in basis differences in AOCI, offset by $53 and $67 at December 31, 2024 and 2023, respectively, due to a tax sharing liability to TTI under a tax sharing agreement. (3) The carrying value of our equity method investment is $41 higher than the underlying equity in the net assets of the investee due to equity method goodwill. (4) The carrying value of our equity method investment is $257 and $262 higher than the underlying equity in the net assets of the investee at December 31, 2024 and 2023, respectively, primarily due to guarantees, interest capitalized on the investment prior to the JV commencing its operations, and amortization of guarantee fees and capitalized interest thereafter. (5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees. (6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill. EARNINGS FROM EQUITY METHOD INVESTMENTS (1) (Dollars in millions) Years ended December 31, 2024 2023 2022 EARNINGS RECORDED BEFORE INCOME TAX (2) : Sempra Texas Utilities: Sharyland Holdings $ 8 $ 7 $ 7 Sempra Infrastructure: Cameron LNG JV (3) 576 586 659 Segment totals 584 593 666 Parent and other – RBS Sempra Commodities LLP 19 40 — 603 633 666 EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 780 694 735 Sempra Infrastructure: IMG 136 40 68 TAG Norte 90 114 29 Segment totals 1,006 848 832 Total $ 1,609 $ 1,481 $ 1,498 (1) All amounts are before NCI, where applicable. (2) We provide our ETR calculation in Note 7. (3) Includes $9 and $12 of basis differences in equity earnings related to AOCI in 2023 and 2022, respectively. We provide the contributions to and distributions from our investments by segment in the following tables. EXPENDITURES FOR INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra Texas Utilities: Oncor Holdings $ 972 $ 363 $ 341 Sharyland Holdings 4 4 5 976 367 346 Sempra Infrastructure: Cameron LNG JV 12 15 30 12 15 30 Total $ 988 $ 382 $ 376 DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra Texas Utilities: Oncor Holdings (1) $ 616 $ 441 $ 340 Sharyland Holdings 4 4 5 620 445 345 Sempra Infrastructure: Cameron LNG JV 453 456 509 IMG 33 11 — TAG Norte 62 36 32 548 503 541 Segment totals 1,168 948 886 Parent and other – RBS Sempra Commodities LLP 9 — — Total $ 1,177 $ 948 $ 886 (1) Includes a $13 noncash return on investment in 2024. When including payments received under a tax sharing agreement, cash and noncash distributions would total $681, $558 and $443 in 2024, 2023 and 2022, respectively. At December 31, 2024 and 2023, our share of the undistributed earnings of equity method investments was $2.9 billion and $2.5 billion, respectively, including $630 million at December 31, 2024 in undistributed earnings from investments for which we have less than 50% equity interests. 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. Sempra does not control Oncor Holdings or Oncor, and the ring-fencing measures, governance mechanisms and commitments in effect limit our ability to direct the management, policies and operations of Oncor Holdings and Oncor, including the deployment or disposition of their assets, declarations of dividends, strategic planning and other important corporate issues and actions. We also have limited representation on the Oncor Holdings and Oncor boards of directors. Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra. Rather, only our pretax equity earnings from our investment in Oncor Holdings (a disregarded entity for tax purposes) are included in our consolidated income tax return. A tax sharing agreement with TTI, Oncor Holdings and Oncor provides for the calculation of an income tax liability substantially as if Oncor Holdings and Oncor were taxed as corporations and requires tax payments determined on that basis. While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and Oncor being subject to the provisions of U.S. GAAP governing rate-regulated operations, Oncor recognizes amounts determined under cost-based regulatory rate-setting processes (with such costs including income taxes), as if it were taxed as a corporation. As a result, since Oncor Holdings consolidates Oncor, we recognize equity earnings from our investment in Oncor Holdings net of its recorded income tax. We provide summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Years ended December 31, 2024 2023 2022 Operating revenues $ 6,082 $ 5,586 $ 5,243 Operating expenses (4,318) (4,026) (3,682) Income from operations 1,764 1,560 1,561 Interest expense (653) (536) (445) Income tax expense (217) (192) (203) Net income 957 849 893 NCI held by TTI (192) (170) (179) Earnings attributable to Sempra (1) 765 679 714 December 31, 2024 2023 Current assets $ 1,638 $ 1,431 Noncurrent assets 38,697 34,649 Current liabilities 2,183 1,625 Noncurrent liabilities 21,958 19,727 NCI held by TTI 3,689 3,338 (1) Excludes adjustments to equity earnings related to amortization of a tax sharing liability associated with a tax sharing agreement and changes in basis differences in AOCI within the carrying value of our equity method investment. SHARYLAND HOLDINGS We account for our 50% ownership interest in Sharyland Holdings, a JV with SU Investment Partners, L.P. that owns a 100% interest in Sharyland Utilities, as an equity method investment. CAMERON LNG JV Cameron LNG JV is a JV between Sempra and three project partners, TotalEnergies SE, Mitsui & Co., Ltd., and Japan LNG Investment, LLC, a company jointly owned by Mitsubishi Corporation and Nippon Yusen Kabushiki Kaisha. We account for SI Partners’ 50.2% investment in Cameron LNG JV under the equity method. 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 December 31, 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 three 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 10). At December 31, 2024, the fair value of the Support Agreement was $25 million, of which $7 million is included in Other Current Assets and $18 million is included in Other Long-Term Assets on Sempra’s Consolidated Balance Sheet. IMG SI Partners’ has a 40% interest in IMG, a JV with a subsidiary of TC Energy Corporation, and accounts for its interest as an equity method investment. IMG owns and operates the Sur de Texas-Tuxpan natural gas marine pipeline, which is fully contracted under a 35-year natural gas transportation service contract with the CFE. TAG NORTE SI Partners’ has a 50% beneficial ownership interest in TAG Norte, a JV with TETL JV Mexico Norte, S. de R.L. de C.V. and Bravo N Mergeco, S. de R.L. de C.V. that owns a 50% interest in the Los Ramones Norte pipeline. SI Partners accounts for its 50% interest in TAG Norte as an equity method investment. RBS SEMPRA COMMODITIES LLP RBS Sempra Commodities LLP is a United Kingdom limited liability partnership formed by Sempra and The Royal Bank of Scotland plc (RBS) in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra. We and RBS sold substantially all of the partnership’s businesses and assets in four separate transactions completed in 2010 and 2011. Since 2011, our investment balance has reflected our share of the remaining partnership assets, including amounts retained by the partnership to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership and the distribution of the partnership’s remaining assets, if any. We accounted for our investment in RBS Sempra Commodities LLP under the equity method. In 2018, we fully impaired our remaining equity method investment in RBS Sempra Commodities LLP. In 2023, we reduced our previously recorded estimate of losses by $40 million based on a settlement that fully resolved legal matters that we discuss in “Legal Proceedings – Other Sempra” in Note 15. In 2024, we substantially completed the dissolution of the partnership, at which time we recorded $19 million ($16 million after tax) in Equity Earnings on Sempra’s Consolidated Statement of Operations. SUMMARIZED FINANCIAL INFORMATION We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings and RBS Sempra Commodities LLP) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Gross revenues $ 2,962 $ 3,083 $ 2,959 Operating expenses (820) (776) (772) Income from operations 2,142 2,307 2,187 Interest expense (547) (570) (505) Net income/Earnings (1)(2) 1,688 1,499 1,537 December 31, 2024 2023 Current assets $ 1,134 $ 1,216 Noncurrent assets 14,687 14,826 Current liabilities 1,130 1,255 Noncurrent liabilities 10,051 10,786 (1) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships. (2) Amounts for Cameron LNG JV exclude adjustments to equity earnings related to amortization of capitalized interest and guarantee fees within the carrying value of our equity method investment and changes in basis differences in equity earnings related to AOCI.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES SHORT-TERM DEBT Committed Lines of Credit At December 31, 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) December 31, 2024 Borrower Expiration date of facility Total facility Commercial Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2029 $ 4,000 $ — $ — $ — $ 4,000 SDG&E October 2029 1,500 (417) — — 1,083 SoCalGas October 2029 1,200 (337) — — 863 SI Partners and IEnova September 2025 500 — (368) — 132 SI Partners and IEnova August 2026 1,000 — — — 1,000 SI Partners and IEnova August 2028 1,500 — (186) — 1,314 Port Arthur LNG March 2030 200 — — (64) 136 Total $ 9,900 $ (754) $ (554) $ (64) $ 8,528 The principal terms of Sempra’s, SDG&E’s and SoCalGas’ lines of credit reflected in the table above include the following: ▪ Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in any facility. ▪ Sempra’s, SDG&E’s and SoCalGas’ facilities provide for the issuance of $200 million, $100 million and $150 million, respectively, of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra, SDG&E and SoCalGas each has the right to increase its letter of credit commitment to up to $500 million, $250 million and $250 million, respectively. ▪ Borrowings bear interest at a benchmark rate plus a margin that varies with the borrower’s credit rating. ▪ Each borrower must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At December 31, 2024, each Registrant was in compliance with this ratio under its respective credit facility. SI Partners and IEnova have three combined lines of credit, reflected in the table above, that require borrowings to be issued in U.S. dollars only and include the following principal terms: ▪ Borrowings on the $500 million revolving credit facility bear interest at a per annum rate equal to term SOFR plus 80 bps (including a credit adjustment spread). ▪ The $1.0 billion facility provides for borrowings of up to $1.0 billion through a syndicate of 12 lenders available to SI Partners and up to $910 million through a syndicate of 11 lenders available to IEnova, subject to a combined borrowing limit of $1.0 billion. This facility: ◦ Charges interest on borrowings at a benchmark rate plus a margin that varies with SI Partners’ credit rating (plus a term SOFR credit adjustment spread of 10 bps in all tenors). ◦ Provides for issuance of up to $200 million of letters of credit, subject to a combined letter of credit commitment of $200 million, which can be issued in U.S. dollars or Mexican pesos, and which reduces available unused credit. ◦ Includes a $100 million swingline loan sub-limit, whereby any outstanding amounts would reduce available unused credit. No swingline loan borrowings were outstanding at December 31, 2024. ◦ Gives either SI Partners or IEnova the right to increase the total facility to $1.5 billion, subject to lender approval, with borrowings of up to $1.5 billion through a syndicate of 12 lenders available to SI Partners and up to $1,365 million through a syndicate of 11 lenders available to IEnova. ▪ Borrowings on the $1.5 billion revolving credit facility, with borrowings of up to $1.5 billion through a syndicate of 12 lenders available to SI Partners and up to $1,365 million through a syndicate of 11 lenders available to IEnova, subject to a combined borrowing limit of $1.5 billion, bear interest at a per annum rate equal to term SOFR plus 90 bps (including a credit adjustment spread). Additionally, 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 December 31, 2024, SI Partners was in compliance with this ratio. Port Arthur LNG has a working capital facility agreement, reflected in the table above, that permits borrowings of up to $200 million, which bear interest by reference to term SOFR plus the applicable margin and a credit adjustment spread. The credit facility also provides for the issuance of up to $200 million of letters of credit, which reduces available unused credit. Uncommitted Line of Credit ECA LNG Phase 1 has an uncommitted line of credit with an aggregate capacity of $100 million that expires in August 2026. Borrowings are generally used for working capital requirements and can be in U.S. dollars or Mexican pesos. At December 31, 2024, ECA LNG Phase 1 had outstanding borrowings of $8 million, before reductions of any unamortized discounts, in Mexican pesos that bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 154 bps. Borrowings made in U.S. dollars bear interest at a variable rate based on the one-month or three-month SOFR plus 164 bps and a credit adjustment spread of 10 bps. Uncommitted Letters of Credit Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At December 31, 2024, we had $497 million in standby letters of credit outstanding under these agreements. UNCOMMITTED LETTERS OF CREDIT OUTSTANDING (Dollars in millions) Expiration date range December 31, 2024 SDG&E January 2025 - November 2025 $ 26 SoCalGas January 2025 - December 2025 20 Other Sempra January 2025 - November 2054 451 Total Sempra $ 497 Term Loan In May 2024, SoCalGas entered into a $500 million, 364-day term loan facility with a maturity date of May 22, 2025, and in December 2024, SoCalGas increased the amount of the term loan to $700 million. At December 31, 2024, SoCalGas had borrowed the full $700 million then available under the term loan, net of negligible debt issuance costs, which is included in Short-Term Debt on SoCalGas’ Balance Sheet. SoCalGas may request a further increase in the term loan facility of up to $300 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. Weighted-Average Interest Rates The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2024 2023 Sempra 5.03 % 5.96 % SDG&E 4.76 — SoCalGas 5.02 5.44 LONG-TERM DEBT The following tables show the detail and maturities of long-term debt outstanding. LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2024 2023 SDG&E: First mortgage bonds (collateralized by plant assets): 2.50% May 15, 2026 $ 500 $ 500 6.00% June 1, 2026 250 250 4.95% August 15, 2028 600 600 1.70% October 1, 2030 800 800 3.00% March 15, 2032 500 500 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 6.00% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.50% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.30% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.10% June 15, 2049 400 400 3.32% April 15, 2050 400 400 2.95% August 15, 2051 750 750 3.70% March 15, 2052 500 500 5.35% April 1, 2053 800 800 5.55% April 15, 2054 600 — 8,950 8,350 Other long-term debt (uncollateralized): Notes at variable rates (5.99% at December 31, 2023) February 18, 2024 (1) — 400 Finance lease obligations: Power purchase agreements 1,138 1,166 Other 67 67 1,205 1,633 10,155 9,983 Current portion of long-term debt and finance leases (42) (441) Unamortized discount on long-term debt (33) (29) Unamortized debt issuance costs (62) (60) Total SDG&E $ 10,018 $ 9,453 (1) Callable long-term debt not subject to make-whole provisions. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ — $ 500 3.20% June 15, 2025 350 350 2.60% June 15, 2026 500 500 2.55% February 1, 2030 650 650 5.20% June 1, 2033 500 500 5.05% September 1, 2034 600 — 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.30% January 15, 2049 550 550 3.95% February 15, 2050 350 350 6.35% November 15, 2052 600 600 5.75% June 1, 2053 500 500 5.60% April 1, 2054 500 — 6,650 6,050 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 2.95% Notes April 15, 2027 700 700 5.67% Notes January 18, 2028 (2) 5 5 Finance lease obligations 110 107 819 816 7,469 6,866 Current portion of long-term debt and finance leases (373) (523) Unamortized discount on long-term debt (18) (13) Unamortized debt issuance costs (47) (42) Total SoCalGas $ 7,031 $ 6,288 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 Other Sempra: Sempra - Other long-term debt (uncollateralized): 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Sempra Infrastructure - Other long-term debt (uncollateralized unless otherwise noted): Loan at variable rates (weighted-average rate of 7.29% and 8.31% at December 31, 2024 and 2023, respectively) December 9, 2025 1,063 832 3.75% Notes January 14, 2028 300 300 Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets (1) 1,090 258 3.25% Notes January 15, 2032 400 400 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable June 15, 2022 through November 19, 2034 (1) 90 96 2.90% Loan payable June 15, 2022 through November 19, 2034 (1) 219 231 4.875% Notes January 14, 2048 540 540 4.75% Notes January 15, 2051 800 800 4,682 3,649 16,590 12,207 Current portion of long-term debt (1,859) (11) Unamortized discount on long-term debt (78) (66) Unamortized debt issuance costs (144) (112) Total Other Sempra 14,509 12,018 Total Sempra $ 31,558 $ 27,759 (1) Callable long-term debt not subject to make-whole provisions. At December 31, 2024, scheduled maturities of long-term debt are as follows: MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Total 2025 $ — $ 350 $ 1,862 $ 2,212 2026 750 504 599 1,853 2027 — 700 799 1,499 2028 600 5 1,358 1,963 2029 — — 584 584 Thereafter 7,600 5,800 11,388 24,788 Total $ 8,950 $ 7,359 $ 16,590 $ 32,899 (1) Excludes finance lease obligations, discounts, and debt issuance costs. Various long-term obligations totaling $16.2 billion at Sempra at December 31, 2024 are unsecured. This includes unsecured long-term obligations totaling $709 million at SoCalGas. Callable Long-Term Debt At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2024 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ — $ 4 $ 6,687 $ 6,691 Subject to make-whole provisions 8,950 7,350 9,903 26,203 First Mortgage Bonds SDG&E and SoCalGas issue first mortgage bonds secured by liens on their respective utility plant assets. SDG&E and SoCalGas may issue additional first mortgage bonds if in compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of additional first mortgage bonds of $8.8 billion at SDG&E and $1.6 billion at SoCalGas at December 31, 2024. 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 Long-Term Debt Other Sempra Sempra. Sempra issued the following fixed-to-fixed reset rate junior subordinated notes in 2024: ▪ In March 2024, Sempra issued $600 million aggregate principal amount of 6.875% junior subordinated notes maturing on October 1, 2054, and received proceeds of $593 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). In May 2024, Sempra issued an additional $500 million aggregate principal amount of these junior subordinated notes and 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. Interest accrues from and including March 14, 2024 to, but excluding, October 1, 2029 at the rate of 6.875% per annum. ▪ In September 2024, Sempra issued $1.25 billion aggregate principal amount of 6.40% junior subordinated notes maturing on October 1, 2054, and received proceeds of $1.235 billion (net of underwriting discounts and debt issuance costs of $15 million). Interest accrues from and including September 9, 2024 to, but excluding, October 1, 2034 at the rate of 6.40% per annum. ▪ In November 2024, Sempra issued $400 million aggregate principal amount of 6.625% junior subordinated notes maturing on April 1, 2055, and received proceeds of $395 million (net of underwriting discounts and debt issuance costs of $5 million). Interest accrues from and including November 21, 2024 to, but excluding, April 1, 2030 at the rate of 6.625% per annum. ▪ In November 2024, Sempra issued $600 million aggregate principal amount of 6.55% junior subordinated notes maturing on April 1, 2055, and received proceeds of $593 million (net of underwriting discounts and debt issuance costs of $7 million). Interest accrues from and including November 21, 2024 to, but excluding, April 1, 2035 at the rate of 6.55% per annum. The interest rates on the notes will be reset on: ▪ October 1, 2029 (for the March 2024 and May 2024 issuances), ▪ October 1, 2034 (for the September 2024 issuance), ▪ April 1, 2030 (for the $400 million November 2024 issuance), and ▪ April 1, 2035 (for the $600 million November 2024 issuance), and on each subsequent five-year period beginning on October 1 or April 1, as applicable, of every fifth year thereafter, 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 ▪ 2.789% (for the March 2024 and May 2024 issuances), ▪ 2.632% (for the September 2024 issuance), ▪ 2.354% (for the $400 million November 2024 issuance), and ▪ 2.138% (for the $600 million November 2024 issuance). Interest is payable on the notes 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) or April 1, 2025 (for the September 2024 and November 2024 issuances). 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), October 1, 2034 (for the September 2024 issuance), April 1, 2030 (for the $400 million November 2024 issuance), and April 1, 2035 (for the $600 million November 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. We used, or plan to use, the proceeds from the offerings for general corporate purposes, including repayment of commercial paper and other indebtedness. ECA LNG Phase 1. ECA LNG Phase 1 has a five Port Arthur LNG. Port Arthur LNG has a seven In November 2024, Port Arthur LNG signed an agreement to issue senior secured notes in January 2025 for $750 million and April 2025 for $250 million. The net proceeds from the January 2025 issuance and the expected net proceeds from the April 2025 issuance were or will be used to pay transaction fees and repay borrowings under the existing Port Arthur LNG term loan facility. The senior secured notes mature in December 2042 and the January 2025 and April 2025 issuances bear interest at the rate of 6.27% and 6.32% per annum, respectively.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Income tax expense $ 219 $ 490 $ 556 Income before income taxes and equity earnings $ 2,110 $ 2,627 $ 1,343 Equity earnings, before income tax (1) 603 633 666 Pretax income $ 2,713 $ 3,260 $ 2,009 Effective income tax rate 8 % 15 % 28 % SDG&E: Income tax expense (benefit) $ 153 $ (26) $ 182 Income before income taxes $ 1,044 $ 910 $ 1,097 Effective income tax rate 15 % (3) % 17 % SoCalGas: Income tax expense (benefit) $ 31 $ (5) $ 138 Income before income taxes $ 987 $ 807 $ 738 Effective income tax rate 3 % (1) % 19 % (1) We discuss how we recognize equity earnings in Note 5. 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. Items subject to flow-through treatment include: ▪ repairs expenditures related to certain utility plant fixed assets ▪ the equity component of AFUDC, which is non-taxable ▪ cost of removal related to certain utility plant assets ▪ utility self-developed software expenditures ▪ depreciation related to certain utility plant assets ▪ state income taxes AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2024 2023 2022 Sempra: U.S. federal statutory income tax rate 21 % 21 % 21 % Valuation allowances 14 — (2) Utility depreciation 4 3 4 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (2) 1 1 3 State income taxes, net of federal income tax benefit 1 1 1 Outside basis differences — — 6 Remeasurement of deferred taxes — (1) (3) Tax credits (1) (5) (1) Utility self-developed software expenditures (1) (1) — Allowance for equity funds used during construction (1) (1) (1) Amortization of excess deferred income taxes (1) (1) (2) Resolution of prior years’ income tax items (2) (2) (2) Noncontrolling interests (3) (3) — Utility repairs expenditures (8) (6) (5) Foreign exchange and inflation effects (1) (14) 9 9 Other, net (2) — — Effective income tax rate 8 % 15 % 28 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 5 3 State income taxes, net of federal income tax benefit 3 2 4 Self-developed software expenditures (1) (1) — Resolution of prior years’ income tax items (1) (1) (2) Amortization of excess deferred income taxes (1) (2) (2) Allowance for equity funds used during construction (1) (2) (2) Tax credits (1) (16) — Repairs expenditures (9) (8) (5) Other, net — (1) — Effective income tax rate 15 % (3) % 17 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 5 5 Nondeductible expenditures — — 2 State income taxes, net of federal income tax benefit (1) (2) 2 Amortization of excess deferred income taxes (1) (2) (2) Allowance for equity funds used during construction (2) (1) (2) Self-developed software expenditures (2) (2) — Resolution of prior years’ income tax items (3) (6) — Repairs expenditures (14) (14) (6) Other, net — — (1) Effective income tax rate 3 % (1) % 19 % (1) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. (2) Related to operations in Mexico. We expect to repatriate approximately $3.1 billion of foreign undistributed earnings in the foreseeable future, and have accrued $100 million of U.S. state deferred income tax liability at December 31, 2024. We repatriated approximately $100 million and $108 million to the U.S. in 2024 and 2023, respectively. In the year ended December 31, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested. We have not recorded deferred income taxes with respect to remaining basis differences of approximately $700 million between financial statement and income tax investment amounts in our non-U.S. subsidiaries because we consider them to be indefinitely reinvested as of December 31, 2024. The remaining basis differences are calculated pursuant to U.S. federal tax law, which may differ from tax law in California and foreign jurisdictions. It is currently not practicable to determine the hypothetical amount of tax that might be payable if the underlying basis differences were realized. The table below presents the geographic location of pretax income. PRETAX INCOME BY GEOGRAPHIC LOCATION (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: U.S. $ 2,354 $ 2,678 $ 1,449 Non-U.S. 359 582 560 Total (1) $ 2,713 $ 3,260 $ 2,009 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the calculation of pretax income. The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Current: U.S. federal $ 73 $ 102 $ — U.S. state (4) 3 (1) Non-U.S. 179 208 165 Total 248 313 164 Deferred: U.S. federal 366 (56) 248 U.S. state 28 18 50 Non-U.S. (422) 225 94 Total (1) (28) 187 392 Deferred investment tax credits (1) (10) — Total income tax expense $ 219 $ 490 $ 556 SDG&E: Current: U.S. federal $ (16) $ (156) $ 76 U.S. state — (5) 13 Total (16) (161) 89 Deferred: U.S. federal 129 111 54 U.S. state 41 35 38 Total 170 146 92 Deferred investment tax credits (1) (11) 1 Total income tax expense (benefit) $ 153 $ (26) $ 182 SoCalGas: Current: U.S. federal $ 3 $ (6) $ (5) U.S. state — (11) (3) Total 3 (17) (8) Deferred: U.S. federal 45 22 125 U.S. state (16) (11) 22 Total 29 11 147 Deferred investment tax credits (1) 1 (1) Total income tax expense (benefit) $ 31 $ (5) $ 138 (1) In 2024 and 2023, Deferred Income Taxes and Investment Tax Credits on the Sempra Consolidated Statements of Cash Flows also includes $9 and $72, respectively, of income taxes included in equity earnings, which are recorded net of income tax under a tax sharing agreement with Oncor. The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES (Dollars in millions) December 31, 2024 2023 Sempra: Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 7,164 $ 6,875 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 79 55 Regulatory balancing accounts 850 727 Right-of-use assets – operating leases 325 211 Property taxes 74 68 Postretirement benefits 150 47 Other deferred income tax liabilities 94 68 Total deferred income tax liabilities 8,736 8,051 Deferred income tax assets: Tax credits 1,485 1,468 Net operating losses 1,105 982 Compensation-related items 225 157 Operating lease liabilities 301 179 Other deferred income tax assets 219 96 Bad debt allowance 151 144 Accrued expenses not yet deductible 80 89 Deferred income tax assets before valuation allowances 3,566 3,115 Less: valuation allowances 503 189 Total deferred income tax assets 3,063 2,926 Net deferred income tax liability (2) $ 5,673 $ 5,125 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2024 and 2023, includes $172 and $129, respectively, recorded as a noncurrent asset and $5,845 and $5,254, respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES (Dollars in millions) SDG&E SoCalGas December 31, 2024 2023 2024 2023 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 2,805 $ 2,641 $ 2,594 $ 2,272 Regulatory balancing accounts 545 418 306 309 Right-of-use assets – operating leases 222 103 5 8 Property taxes 47 43 27 25 Postretirement benefits — — 124 71 Other deferred income tax liabilities — — 2 4 Total deferred income tax liabilities 3,619 3,205 3,058 2,689 Deferred income tax assets: Tax credits 8 7 2 7 Compensation-related items 8 9 26 31 Operating lease liabilities 222 103 5 8 Bad debt allowance 29 37 72 86 Accrued expenses not yet deductible 10 11 54 56 Net operating losses 122 146 874 890 Other deferred income tax assets 9 19 20 25 Total deferred income tax assets 408 332 1,053 1,103 Net deferred income tax liability $ 3,211 $ 2,873 $ 2,005 $ 1,586 The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2024 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,091 2037 General business tax credits (1) 126 2043 Corporate alternative minimum tax credits (1) 676 Indefinite Foreign tax credits (2) 706 2025 U.S. state: NOLs (2) 5,912 2027 General business tax credits (1) 24 2027 Non-U.S. (2) : NOLs 782 2025 Foreign tax credits 5 Indefinite SDG&E: U.S. federal (1) : NOLs $ 279 Indefinite General business tax credits 1 2044 U.S. state NOLs (1) 909 2043 SoCalGas: U.S. federal NOLs (1) $ 2,857 Indefinite U.S. state NOLs (1) 3,917 2042 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as we discuss below. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred income tax asset in the future. In the year ended December 31, 2024, we recognized income tax expense of $330 million from changes to a valuation allowance against foreign tax credits that were carried forward from the implementation of the Tax Cuts and Jobs Act of 2017. For various U.S. state and non-U.S. jurisdictions, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses resulting in deferred income tax assets that we currently do not believe will be realized on a more-likely-than-not basis. The following table provides the valuation allowances that we recorded against a portion of our total deferred income tax assets shown above in the “Deferred Income Taxes – Sempra” table. VALUATION ALLOWANCES BY JURISDICTION (Dollars in millions) December 31, 2024 2023 Sempra: U.S. federal $ 406 $ 108 U.S. state 47 51 Non-U.S. 50 30 $ 503 $ 189 Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2024 2023 2022 Sempra: Balance at January 1 $ 492 $ 278 $ 304 Increase in prior period tax positions 40 308 16 Decrease in prior period tax positions (8) (63) (2) Decrease in current period tax positions — (21) — Settlements with tax authorities (15) (16) (43) Expiration of statutes of limitations — — (1) Increase in current period tax positions 39 6 4 Balance at December 31 $ 548 $ 492 $ 278 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (229) $ (224) $ (117) increase the effective tax rate (1) 1 1 38 SDG&E: Balance at January 1 $ 14 $ 14 $ 14 Increase in prior period tax positions — 2 — Settlements with tax authorities — (2) — Balance at December 31 $ 14 $ 14 $ 14 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (11) $ (11) $ (11) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 29 $ 77 $ 72 Increase in prior period tax positions — 1 1 Decrease in prior period tax positions — (47) — Increase in current period tax positions — — 4 Settlements with tax authorities — (2) — Balance at December 31 $ 29 $ 29 $ 77 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (29) $ (29) $ (67) increase the effective tax rate (1) — — 37 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. The California Franchise Tax Board is examining Sempra’s California unitary group for tax years 2018 and 2019. As of December 31, 2024, it is not reasonably possible this matter could be resolved within the next 12 months. We have included an increase in unrecognized income tax benefits in the reconciliation above. In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. SDG&E and SoCalGas elected this change in tax accounting method in Sempra’s consolidated 2023 income tax return filing and recorded additional income tax benefits of $34 million and $97 million, respectively, in 2023. Additionally, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and recorded an income tax benefit of $43 million in 2023 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. Sempra, SDG&E, and SoCalGas record regulatory liabilities for benefits that will be flowed through to customers in the future. It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) December 31, 2024 2023 2022 Sempra: Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities $ 15 $ 242 $ 8 SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 6 $ 6 $ 6 SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 2 $ 2 $ 2 Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in Income Tax Expense (Benefit) on the Consolidated Statements of Operations. Sempra accrued $15 million at both December 31, 2024 and 2023 on the Consolidated Balance Sheets, and negligible amounts in 2024, $2 million in 2023 and negligible amounts in 2022 on the Consolidated Statements of Operations for interest and penalties. SDG&E and SoCalGas each accrued negligible amounts for interest expense and penalties at December 31, 2024 and 2023 on the Consolidated Balance Sheets, and recorded negligible amounts for interest expense and penalties on the Consolidated Statements of Operations for all periods presented. INCOME TAX AUDITS Sempra is subject to U.S. federal income tax as well as income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2020. We are subject to examination by major state tax jurisdictions for tax years after 2012. Certain major non-U.S. income tax returns for tax years 2013 through the present are open to examination. SDG&E and SoCalGas are subject to U.S. federal income tax and state income tax. They remain subject to examination for U.S. federal tax years after 2020 and state tax years after 2012. In addition, Sempra has filed protests to contest proposed state audit adjustments for tax years 2009 through 2012. The pre-2013 tax years for our major state tax jurisdictions are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these tax years. SI Partners has filed an administrative appeal to contest a tax assessment issued by the Servicio de Administración Tributaria for tax year 2016. In 2023, we increased unrecognized income tax benefits in the table above, and will have the opportunity to contest any unresolved issues through the Mexican courts.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
Employee Benefit Plans	EMPLOYEE BENEFIT PLANS For our employee benefit plans, we: ▪ recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the balance sheet; ▪ measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year; and ▪ recognize changes in the funded status of pension and PBOP plans in the year in which the changes occur. Generally, those changes are reported in OCI and as a separate component of shareholders’ equity. The detailed information presented below covers the employee benefit plans of primarily Sempra and its consolidated entities. Sempra has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas, which collectively cover all eligible employees. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology. IEnova has an unfunded noncontributory defined benefit plan covering all employees that provides defined benefits to retirees based on date of hire, years of service and final average earnings. Sempra also has PBOP plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. PBOP plans include medical benefits. Pension and PBOP costs and obligations are dependent on assumptions used in calculating such amounts. We review these assumptions on an annual basis and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. 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 December 31, 2024 and 2023, respectively. PENSION AND PBOP PLANS Oncor In 2024 and 2023, we had $34 million and $38 million, respectively, in AOCI representing an actuarial loss related to Oncor’s pension plans. Benefit Obligations and Assets The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2024 and 2023, and a statement of the funded status at December 31, 2024 and 2023. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP 2024 2023 2024 2023 Sempra: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 3,107 $ 2,806 $ 693 $ 663 Service cost 132 109 15 13 Interest cost 166 157 36 37 Contributions from plan participants — — 23 23 Actuarial (gain) loss (100) 190 (11) 28 Plan amendments 2 4 — — Benefit payments (81) (83) (69) (71) Settlements (87) (76) — — Obligation at December 31 3,139 3,107 687 693 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,664 2,390 1,169 1,096 Actual return on plan assets 196 218 57 117 Employer contributions 243 215 5 4 Contributions from plan participants — — 23 23 Benefit payments (81) (83) (69) (71) Settlements (87) (76) — — Fair value of plan assets at December 31 2,935 2,664 1,185 1,169 Funded status at December 31 $ (204) $ (443) $ 498 $ 476 Net recorded (liability) asset at December 31 $ (204) $ (443) $ 498 $ 476 (1) The accumulated benefit obligation was $2,900 and $2,865 at December 31, 2024 and 2023, respectively. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP 2024 2023 2024 2023 SDG&E: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 807 $ 714 $ 140 $ 134 Service cost 39 32 3 3 Interest cost 43 40 7 8 Contributions from plan participants — — 8 8 Actuarial (gain) loss (28) 69 (6) 7 Benefit payments (16) (17) (18) (20) Settlements (23) (31) — — Obligation at December 31 822 807 134 140 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 726 670 150 147 Actual return on plan assets 63 52 5 14 Employer contributions 37 52 — 1 Contributions from plan participants — — 8 8 Benefit payments (16) (17) (18) (20) Settlements (23) (31) — — Fair value of plan assets at December 31 787 726 145 150 Funded status at December 31 $ (35) $ (81) $ 11 $ 10 Net recorded (liability) asset at December 31 $ (35) $ (81) $ 11 $ 10 (1) The accumulated benefit obligation was $781 and $769 at December 31, 2024 and 2023, respectively. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP (Dollars in millions) 2024 2023 2024 2023 SoCalGas: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 1,977 $ 1,814 $ 521 $ 497 Service cost 79 65 11 9 Interest cost 105 101 27 28 Contributions from plan participants — — 14 14 Actuarial (gain) loss (70) 90 (4) 21 Plan amendments 2 — — — Benefit payments (56) (58) (47) (48) Settlements (38) (35) — — Obligation at December 31 1,999 1,977 522 521 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,744 1,535 990 923 Actual return on plan assets 115 151 50 100 Employer contributions 172 151 1 1 Contributions from plan participants — — 14 14 Benefit payments (56) (58) (47) (48) Settlements (38) (35) — — Fair value of plan assets at December 31 1,937 1,744 1,008 990 Funded status at December 31 $ (62) $ (233) $ 486 $ 469 Net recorded (liability) asset at December 31 $ (62) $ (233) $ 486 $ 469 (1) The accumulated benefit obligation was $1,824 and $1,799 at December 31, 2024 and 2023, respectively. Actuarial (gains) losses fluctuate based on changes in assumptions that we describe below in “Assumptions for Pension and PBOP Plans” and updates to census data. Pension Plans ▪ In 2024, actuarial gains were driven by an increase in discount rates at SoCalGas and SDG&E, offset by updated census data at SoCalGas and SDG&E. ▪ In 2023, actuarial losses were driven by a decrease in discount rates at SoCalGas and SDG&E, an increase in the interest crediting rate for cash balance plans at SDG&E and SoCalGas and updated census data at Sempra and SDG&E. These actuarial losses were partially offset by actuarial gains at SoCalGas due to a change in the rates to convert traditional pension benefits to lump-sums. PBOP Plans ▪ In 2024, actuarial gains were driven by an increase in discount rates at SoCalGas, partially offset by an increase in the 2025 expected healthcare costs at SoCalGas. ▪ In 2023, actuarial losses were driven by a decrease in discount rates at SoCalGas and SDG&E. Net Assets and Liabilities The assets and liabilities of the pension and PBOP plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and PBOP costs over a period of years. Our funded pension and PBOP plans use the asset smoothing method, except for those at SDG&E. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-plan-assets component of net periodic benefit cost. SDG&E does not use the asset smoothing method but rather recognizes realized and unrealized investment gains and losses during the current year. The 10% corridor accounting method is used at Sempra, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants (or, for plans where participants are substantially inactive employees, the average remaining lifetime of all participants or the period for which benefits will be paid, whichever is shorter). The asset smoothing and 10% corridor accounting methods help mitigate volatility of net periodic benefit costs from year to year. Defined benefit pension and PBOP plans with an aggregated overfunded status are recognized as an asset and with an aggregated underfunded status are recognized as a liability; unrecognized changes in these assets and/or liabilities are normally recorded in AOCI on the balance sheet. SDG&E and SoCalGas record regulatory assets and liabilities that offset the funded pension and PBOP plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on decisions by regulatory agencies. SDG&E and SoCalGas record annual pension and PBOP net periodic benefit costs equal to the contributions to their qualified plans as authorized by the CPUC. The annual contributions to the pension plans are the greater of: ▪ a minimum required funding amount as required by the IRS; ▪ the amount required to maintain an 85% Adjusted Funding Target Attainment Percentage as defined by the Pension Protection Act of 2006, as amended; or ▪ beginning January 1, 2024 and for the duration of the 2024 GRC cycle, a fixed amount equal to the estimated annual service cost as defined by U.S. GAAP plus one year of a seven-year amortization of the unfunded projected benefit obligation of the pension plan as of January 1, 2024, and limited to an annual amount that keeps the fair value of the pension plan assets from exceeding 110% of the pension benefit obligation of the plan. The annual contributions to PBOP plans are equal to the lesser of the maximum tax-deductible amount or the net periodic benefit cost calculated in accordance with U.S. GAAP for pension and PBOP plans but not less than benefits paid directly by the employer (such as benefits paid to key employees). Any differences between booked net periodic benefit cost and amounts contributed to the pension and PBOP plans for SDG&E and SoCalGas are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. The net (liability) asset is included in the following categories on the Consolidated Balance Sheets. PENSION AND PBOP OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Noncurrent assets $ 6 $ — $ 507 $ 485 Current liabilities (50) (44) (1) (1) Noncurrent liabilities (160) (399) (8) (8) Net recorded (liability) asset $ (204) $ (443) $ 498 $ 476 SDG&E: Noncurrent assets $ — $ — $ 11 $ 10 Current liabilities (7) (2) — — Noncurrent liabilities (28) (79) — — Net recorded (liability) asset $ (35) $ (81) $ 11 $ 10 SoCalGas: Noncurrent assets $ — $ — $ 486 $ 469 Current liabilities (17) (2) — — Noncurrent liabilities (45) (231) — — Net recorded (liability) asset $ (62) $ (233) $ 486 $ 469 Amounts recorded in AOCI, net of income tax effects and amounts recorded as regulatory assets, are as follows. AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Net actuarial (loss) gain $ (120) $ (124) $ 14 $ 13 Prior service cost (9) (6) — — Total $ (129) $ (130) $ 14 $ 13 SDG&E: Net actuarial loss $ (12) $ (8) Total $ (12) $ (8) SoCalGas: Net actuarial loss $ (14) $ (10) Prior service cost (3) (2) Total $ (17) $ (12) Sempra, SDG&E and SoCalGas each have a funded pension plan. The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets. OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Projected benefit obligation $ 2,752 $ 2,925 Accumulated benefit obligation 2,542 2,712 Fair value of plan assets 2,724 2,664 SDG&E: Projected benefit obligation $ 793 $ 781 Accumulated benefit obligation 755 746 Fair value of plan assets 787 726 SoCalGas: Projected benefit obligation $ 1,959 $ 1,944 Accumulated benefit obligation 1,787 1,771 Fair value of plan assets 1,937 1,744 We also have unfunded pension plans at Sempra, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans. OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Projected benefit obligation $ 183 $ 182 Accumulated benefit obligation 159 153 SDG&E: Projected benefit obligation $ 29 $ 26 Accumulated benefit obligation 26 23 SoCalGas: Projected benefit obligation $ 40 $ 33 Accumulated benefit obligation 37 28 Sempra, SDG&E and SoCalGas each have a funded PBOP plan. At December 31, 2024, Sempra’s, SDG&E’s and SoCalGas’ plan assets were each in excess of their respective obligations for funded PBOP plans with accumulated postretirement benefit obligations. We also have unfunded PBOP plans at Sempra. The following table shows the obligations of unfunded PBOP plans. OBLIGATIONS OF UNFUNDED PBOP PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Accumulated postretirement benefit obligation $ 9 $ 9 Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost (which, other than the service cost component, are included in Other Income, Net) and pretax amounts recognized in OCI. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 Sempra: NET PERIODIC BENEFIT COST Service cost $ 132 $ 109 $ 146 $ 15 $ 13 $ 23 Interest cost 166 157 118 36 37 28 Expected return on plan assets (178) (169) (183) (70) (69) (64) Amortization of: Prior service cost (credit) 5 5 10 (2) (2) (2) Actuarial loss (gain) 14 10 25 (17) (23) (15) Settlement charges 9 — 28 — — — Net periodic benefit cost (credit) 148 112 144 (38) (44) (30) Regulatory adjustment 100 117 84 38 43 30 Total expense (income) recognized 248 229 228 — (1) — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net (gain) loss (2) 42 12 (1) (2) (4) Prior service cost 3 4 — — — — Amortization of actuarial (loss) gain (7) (5) (8) 1 2 1 Amortization of prior service cost (3) (2) (4) — — — Settlements (9) — — — — — Total recognized in OCI (18) 39 — — — (3) Total recognized in net periodic benefit cost and OCI $ 230 $ 268 $ 228 $ — $ (1) $ (3) NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 SDG&E: NET PERIODIC BENEFIT COST Service cost $ 39 $ 32 $ 37 $ 3 $ 3 $ 5 Interest cost 43 40 26 7 8 6 Expected return on plan assets (45) (39) (46) (9) (8) (10) Amortization of: Prior service cost 1 1 1 — — — Actuarial loss (gain) 8 4 1 (1) (2) (2) Settlement charges — — 14 — — — Net periodic benefit cost (credit) 46 38 33 — 1 (1) Regulatory adjustment (8) 15 20 — — 1 Total expense recognized 38 53 53 $ — $ 1 $ — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 4 3 (3) Amortization of actuarial loss (1) — (1) Amortization of prior service cost — (1) — Total recognized in OCI 3 2 (4) Total recognized in net periodic benefit cost and OCI $ 41 $ 55 $ 49 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 SoCalGas: NET PERIODIC BENEFIT COST Service cost $ 79 $ 65 $ 96 $ 11 $ 9 $ 17 Interest cost 105 101 81 27 28 21 Expected return on plan assets (121) (119) (126) (59) (59) (53) Amortization of: Prior service cost (credit) 4 4 8 (3) (2) (2) Actuarial loss (gain) 1 1 18 (14) (19) (12) Settlement charges — — 14 — — — Net periodic benefit cost (credit) 68 52 91 (38) (43) (29) Regulatory adjustment 108 102 64 38 43 29 Total expense recognized 176 154 155 $ — $ — $ — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 4 2 (5) Prior service cost 2 — — Amortization of actuarial loss (1) (1) (2) Amortization of prior service cost (1) (1) (1) Total recognized in OCI 4 — (8) Total recognized in net periodic benefit cost and OCI $ 180 $ 154 $ 147 Assumptions for Pension and PBOP Plans Benefit Obligation and Net Periodic Benefit Cost Except for the IEnova plans, we develop the discount rate assumptions using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high-quality corporate bonds that generate sufficient cash flows to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of corporate bonds with a Bloomberg Composite of AA or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plans’ projected benefit payments discounted at this rate with the market value of the bonds selected. We develop the discount rate assumptions for the plans at IEnova by constructing a synthetic government zero coupon bond yield curve from the available market data, based on duration matching, and we add a risk spread to allow for the yields of high-quality corporate bonds. Such method is required when there is no deep market for high quality corporate bonds. Expected return on plan assets is based on the weighted average of the plans’ target investment allocation as of the measurement date and the expected returns for those asset types. Interest crediting rate is based on an average 30-year Treasury bond from the month of November of the preceding year. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under U.S. GAAP. The significant assumptions affecting projected benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE PROJECTED BENEFIT OBLIGATION Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Discount rate 5.74 % 5.31 % 5.75 % 5.34 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 5.75 % 5.30 % 5.75 % 5.30 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 SoCalGas: Discount rate 5.70 % 5.25 % 5.75 % 5.35 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for PBOP applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 Sempra: Discount rate 5.31 % 5.63 % 3.04 % 5.34 % 5.65 % 3.04 % Expected return on plan assets 6.56 6.48 6.27 5.90 5.51 4.77 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 5.30 % 5.60 % 2.99 % 5.30 % 5.65 % 3.05 % Expected return on plan assets 6.25 6.00 5.50 5.88 5.52 4.80 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 SoCalGas: Discount rate 5.25 % 5.60 % 3.04 % 5.35 % 5.65 % 3.05 % Expected return on plan assets 6.75 6.75 6.75 5.86 5.47 4.71 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for PBOP applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. Health Care Cost Trend Rates Assumed health care cost trend rates have a significant effect on the amounts that Sempra, SDG&E and SoCalGas report for the health care plan costs. Following are the health care cost trend rates applicable to our PBOP plans: ASSUMED HEALTH CARE COST TREND RATES PBOP Pre-65 retirees Retirees aged 65 years and older Years ended December 31, 2024 2023 2022 2024 2023 2022 Health care cost trend rate assumed for next year 6.50 % 6.00 % 6.00 % 4.50 % 4.50 % 4.50 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2030 2028 2028 2022 2022 2022 Plan Assets Investment Strategy for Sempra’s Pension Master Trust Sempra’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. We maintain additional trusts, as we discuss below, for certain of SDG&E’s and SoCalGas’ PBOP plans. Other than through indexing and certain collective investment strategies, the trusts do not invest in securities of Sempra. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. A portion of the pension master trust is invested in accordance with plan specific de-risking glidepaths designed to reduce the assets’ exposure to risk as the plans become better funded. We assess the portfolio performance by comparing actual returns with relevant benchmarks. The target asset allocations for Sempra’s pension plans are between return-seeking assets (i.e., generally, equity securities, diversified real assets, high-yield fixed income securities and other instruments with a similar risk profile) and risk-mitigating assets (i.e., generally, government and corporate fixed income securities) as follows: TARGET ASSET ALLOCATIONS FOR PENSION PLANS (Dollars in millions) Sempra SDG&E SoCalGas Return-seeking assets 34 % 42 % 49 % Risk-mitigating assets 66 % 58 % 51 % We maintain asset allocations at strategic levels within reasonable bands of variance. The asset allocations are reviewed by our Plan Funding Committee and our Pension and Benefits Investment Committee (the Committees) on a regular basis to help ensure that plan assets are positioned to meet plan obligations. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪ long-term cost ▪ variability and level of contributions ▪ funded status ▪ a range of expected outcomes over varying confidence levels In accordance with the Sempra pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on plan assets in our pension and PBOP plans is based on the weighted average of the plans’ target investment allocations to specific asset classes as of the measurement date. We expect a return of between 4% and 12% on return-seeking assets and between 2% and 6% for risk-mitigating assets. Certain trusts that hold assets for SDG&E’s and SoCalGas’ PBOP plans are subject to taxation, which impacts the expected after-tax return on plan assets. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. Investment Strategy for Sempra’s, SDG&E’s and SoCalGas’ PBOP Plans Sempra’s PBOP plan is funded by cash contributions from Sempra. SDG&E’s and SoCalGas’ PBOP plans are funded by cash contributions from SDG&E and SoCalGas and their current retirees. The assets of these plans are placed into the pension master trust and other Voluntary Employee Beneficiary Association trusts. Specific target asset allocations are periodically reviewed to help ensure that plan assets are positioned to meet plan obligations. The target asset allocations for the PBOP plans are between return-seeking assets and risk-mitigating assets as follows: TARGET ASSET ALLOCATIONS FOR PBOP PLANS (Dollars in millions) Sempra SDG&E and SoCalGas Assets held in pension master trust Assets held in pension master trust Assets held in Voluntary Employee Beneficiary Association trusts Return-seeking assets 74 % 38 % 30 % Risk-mitigating assets 26 % 62 % 70 % Fair Value of Pension and PBOP Plan Assets We classify the investments in Sempra’s pension master trust and the trusts for SDG&E’s and SoCalGas’ PBOP plans based on the fair value hierarchy, except for certain investments measured using NAV as a practical expedient for fair value. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and PBOP plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Registered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices. Where the value is a quoted price in an active market, the investment is classified within Level 1 of the fair value hierarchy. Other investments are valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Certain high yield fixed-income securities are valued by applying a price adjustment to the bid side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Common/Collective Trusts – Investments in common/collective trust funds are valued based on the NAV of units owned, which is based on the current fair value of the funds’ underlying assets. Derivative Financial Instruments – Futures contracts that are publicly traded in active markets are valued at closing prices as of the last business day of the year. Forward currency contracts are valued at the prevailing forward exchange rate of the underlying currencies, and unrealized gain (loss) is recorded daily. Fixed income futures and options are marked to market daily. Equity index futures contracts are valued at the last sales price quoted on the exchange on which they primarily trade. While management believes the valuation methods described above are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. We provide more discussion of fair value measurements in Notes 1 and 10. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and PBOP plan trusts measured at fair value on a recurring basis. The fair values by asset category are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 2 $ — $ 2 Equity securities: Domestic 9 — 9 International 5 — 5 Registered investment companies – Domestic 48 — 48 Fixed income securities: Domestic government and government agencies 227 5 232 International government bonds — 3 3 Domestic corporate bonds — 65 65 International corporate bonds — 8 8 Derivative financial instruments 6 — 6 Total investment assets in the fair value hierarchy 297 81 378 Accounts receivable/payable, net 3 Investments measured at NAV – Common/collective trusts 406 Total SDG&E investment assets 787 SoCalGas: Cash and cash equivalents 8 — 8 Equity securities: Domestic 27 — 27 International 14 — 14 Registered investment companies – Domestic 149 — 149 Fixed income securities: Domestic government and government agencies 270 17 287 International government bonds — 9 9 Domestic corporate bonds — 201 201 International corporate bonds — 26 26 Derivative financial instruments (4) 1 (3) Total investment assets in the fair value hierarchy 464 254 718 Accounts receivable/payable, net 22 Investments measured at NAV – Common/collective trusts 1,197 Total SoCalGas investment assets 1,937 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total Other Sempra: Equity securities: Domestic $ 2 $ — $ 2 International 1 — 1 Registered investment companies – Domestic 10 — 10 Fixed income securities: Domestic government and government agencies 77 3 80 International government bonds — 1 1 Domestic corporate bonds — 14 14 International corporate bonds — 2 2 Derivative financial instruments 1 — 1 Total investment assets in the fair value hierarchy 91 20 111 Accounts receivable/payable, net 1 Investments measured at NAV – Common/collective trusts 99 Total Other Sempra investment assets 211 Total Sempra investment assets in the fair value hierarchy $ 852 $ 355 Total Sempra investment assets $ 2,935 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 17 $ — $ 17 Equity securities: Domestic 103 — 103 International 40 — 40 Registered investment companies – Domestic 41 — 41 Fixed income securities: Domestic government and government agencies 240 5 245 International government bonds — 2 2 Domestic corporate bonds — 62 62 International corporate bonds — 8 8 Derivative financial instruments (15) — (15) Total investment assets in the fair value hierarchy 426 77 503 Accounts receivable/payable, net 1 Investments measured at NAV: Common/collective trusts 214 Other 8 Total SDG&E investment assets 726 SoCalGas: Cash and cash equivalents 3 — 3 Equity securities: Domestic 353 1 354 International 137 — 137 Registered investment companies – Domestic 141 1 142 Fixed income securities: Domestic government and government agencies 310 16 326 International government bonds — 5 5 Domestic corporate bonds — 212 212 International corporate bonds — 27 27 Derivative financial instruments 11 — 11 Total investment assets in the fair value hierarchy 955 262 1,217 Accounts receivable/payable, net (12) Investments measured at NAV: Common/collective trusts 513 Other 26 Total SoCalGas investment assets 1,744 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total Other Sempra: Cash and cash equivalents $ 7 $ — $ 7 Equity securities: Domestic 22 1 23 International 8 — 8 Registered investment companies – Domestic 8 — 8 Fixed income securities: Domestic government and government agencies 78 2 80 Domestic corporate bonds — 13 13 International corporate bonds — 2 2 Derivative financial instruments (5) — (5) Total investment assets in the fair value hierarchy 118 18 136 Investments measured at NAV: Common/collective trusts 56 Other 2 Total Other Sempra investment assets 194 Total Sempra investment assets in the fair value hierarchy $ 1,499 $ 357 Total Sempra investment assets $ 2,664 The fair values by asset category of the PBOP plan assets held in the pension master trust and in the additional trusts for SoCalGas’ PBOP plans and SDG&E’s PBOP plan trusts are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PBOP PLANS (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 1 $ — $ 1 Equity securities – Domestic 1 — 1 Registered investment companies: Domestic 74 — 74 International 8 — 8 Fixed income securities: Domestic government and government agencies 8 — 8 Domestic corporate bonds — 5 5 International corporate bonds — 1 1 Derivative financial instruments (1) — (1)

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 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 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 (1) 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, (2) principal settlements of interest rate swaps associated with capitalized interest costs incurred to finance capital projects as investing activities, and (3) settlements of other derivative instruments as operating activities on the Consolidated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk 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 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 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 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) December 31, Commodity Unit of measure 2024 2023 Sempra: Natural gas MMBtu 637 361 Electricity MWh — 1 Congestion revenue rights MWh 27 36 SDG&E: Natural gas MMBtu 16 17 Congestion revenue rights MWh 27 36 SoCalGas: Natural gas MMBtu 347 268 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 net income 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. On December 31, 2024, Port Arthur LNG voluntarily de-designated the remaining interest rate swaps, which are currently hedging interest payments until March 2026. At the time of de-designation, $37 million of deferred gains related to the de-designated notional amount were included in AOCI, which will remain in AOCI until either the hedged interest payments impact net income or such hedged interest payments become probable of not occurring. 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) December 31, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Cash flow hedges (1) $ 271 2025-2034 $ 4,451 2024-2048 Undesignated derivatives 3,189 2025-2048 — — (1) At December 31, 2024 and 2023, cash flow hedges accrued interest based on a notional amount of $271 and $488, respectively. FOREIGN CURRENCY DERIVATIVES We may utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican fixed interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. 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) December 31, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Foreign currency derivatives $ 162 2025-2026 $ 176 2024-2025 FINANCIAL STATEMENT PRESENTATION The Consolidated Balance Sheets reflect the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Consolidated Balance Sheets, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions. We discuss the fair value of derivative assets and liabilities in Note 10. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 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 $ 7 $ 28 $ — $ — Foreign exchange instruments 4 1 — — Derivatives not designated as hedging instruments: Interest rate instruments 12 246 — — Commodity contracts not subject to rate recovery 16 23 (21) (43) Associated offsetting commodity contracts (15) (23) 15 23 Commodity contracts subject to rate recovery 7 4 (55) (10) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 26 277 (46) (24) Additional cash collateral for commodity contracts not subject to rate recovery 40 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (2) $ 91 $ 277 $ (46) $ (24) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ 4 $ (13) $ (6) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 2 2 (1) — Additional cash collateral for commodity contracts subject to rate recovery 21 — — — Total (2) $ 23 $ 2 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (42) $ (4) Associated offsetting commodity contracts (3) — 3 — Net amounts presented on the balance sheet — — (39) (4) Additional cash collateral for commodity contracts subject to rate recovery 4 — — — Total $ 4 $ — $ (39) $ (4) (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 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 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 Consolidated Statements of Operations and in OCI and AOCI. HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax gain (loss) reclassified Years ended December 31, Years ended December 31, 2024 2023 2022 Location 2024 2023 2022 Sempra: Cash flow hedges: Interest rate instruments $ 36 $ 45 $ 40 Interest expense $ 11 $ (1) $ (1) Interest rate instruments 21 20 205 Equity earnings (1) 23 48 (29) Foreign exchange instruments 14 (2) (8) Revenues: Energy- related businesses 5 (1) 1 Other income, net 2 (2) (1) Foreign exchange instruments 12 (3) (5) Equity earnings (1) 6 (2) — Interest rate and foreign exchange instruments — 7 25 Interest expense — 1 2 Other income, net — 6 12 Fair value hedges: Foreign exchange instruments 2 — — Equity earnings (1) — — — Total $ 85 $ 67 $ 257 $ 47 $ 49 $ (16) SoCalGas: Cash flow hedges: Interest rate instruments $ — $ — $ — Interest expense $ (1) $ (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 $29 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $10 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 December 31, 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 one The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2024 2023 2022 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-related businesses $ 223 $ 919 $ (1,116) Commodity contracts subject to rate recovery Cost of natural gas (56) (288) (56) Commodity contracts subject to rate recovery Cost of electric fuel and purchased power (41) 15 202 Interest rate instruments Interest expense 243 (47) 33 Total $ 369 $ 599 $ (937) SDG&E: Commodity contracts subject to rate recovery Cost of electric fuel and purchased power $ (41) $ 15 $ 202 SoCalGas: Commodity contracts subject to rate recovery Cost of natural gas $ (56) $ (288) $ (56) 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 December 31, 2024 and 2023 was $122 million and $215 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at December 31, 2024 and 2023 was $42 million and $210 million, respectively. SDG&E had a negligible amount of derivative instruments in a liability position at December 31, 2024 and no such instruments at December 31, 2023. At December 31, 2024, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $120 million and $42 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS 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 December 31, 2024 and 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. The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following: ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate instruments and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and, until December 31, 2022, fixed-price electricity positions, at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” We further discuss derivative assets and liabilities in Note 9. ▪ 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) Fair value at December 31, 2024 Level 1 Level 2 Level 3 Netting (1) Total Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 8 $ 2 $ — $ 10 Equity securities 295 3 — 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 26 — 67 Municipal bonds — 287 — 287 Other securities — 228 — 228 Total debt securities 41 541 — 582 Total nuclear decommissioning trusts (2) 344 546 — 890 Short-term investments held in Rabbi Trust 64 — — 64 Support Agreement, net of related guarantee fees — — 25 25 Interest rate instruments — 293 — $ — 293 Foreign exchange instruments — 5 — — 5 Commodity contracts not subject to rate recovery — 39 — 2 41 Commodity contracts subject to rate recovery 6 1 4 18 29 Total $ 414 $ 884 $ 29 $ 20 $ 1,347 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ 63 $ — $ (38) $ 26 Commodity contracts subject to rate recovery 20 45 — (21) 44 Total $ 21 $ 108 $ — $ (59) $ 70 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 December 31, 2024 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 8 $ 2 $ — $ 10 Equity securities 295 3 — 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 26 — 67 Municipal bonds — 287 — 287 Other securities — 228 — 228 Total debt securities 41 541 — 582 Total nuclear decommissioning trusts (2) 344 546 — 890 Commodity contracts subject to rate recovery 4 — 4 $ 17 25 Total $ 348 $ 546 $ 4 $ 17 $ 915 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 December 31, 2024 SoCalGas: Assets: Commodity contracts subject to rate recovery $ 2 $ 1 $ — $ 1 $ 4 Liabilities: Commodity contracts subject to rate recovery $ 2 $ 44 $ — $ (3) $ 43 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 and, until December 31, 2022, fixed-price electricity positions, classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) 2024 2023 2022 Balance at January 1 $ 10 $ 35 $ 54 Realized and unrealized gains (losses), net (10) (17) (56) Allocated transmission instruments 3 (1) (4) Settlements 1 (7) 41 Balance at December 31 $ 4 $ 10 $ 35 Change in unrealized losses relating to instruments still held at December 31 $ (4) $ (13) $ (10) (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 and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following year. For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below: CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2025 $ (7.38) to $ 15.54 $ 0.01 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 9. Long-term, fixed-price electricity positions in 2022 that were valued using significant unobservable data were classified as Level 3 because the contract terms related to a delivery location or tenor for which observable market rate information was not available. The fair value of the net electricity positions classified as Level 3 was derived from a discounted cash flow model using market electricity forward price inputs. The range and weighted-average price of these inputs at December 31, 2022 were $33.45 to $274.70 and $85.64, respectively. Realized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. 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) 2024 2023 2022 Balance at January 1 $ 23 $ 17 $ 7 Realized and unrealized gains (losses), net (1) 11 15 19 Settlements (9) (9) (9) Balance at December 31 (2) $ 25 $ 23 $ 17 Change in unrealized gains relating to instruments still held at December 31 $ 8 $ 13 $ 18 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations. (2) Balance at December 31, 2024 and 2023 includes $7 in Other Current Assets, and $18 and $16, respectively, in Other Long-Term Assets on Sempra’s 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 Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value amount Level 1 Level 2 Level 3 Total December 31, 2024 Sempra: Long-term note receivable (1) $ 351 $ — $ — $ 334 $ 334 Long-term amounts due to unconsolidated affiliates 352 — 324 — 324 Total long-term debt (2) 32,899 — 30,193 — 30,193 SDG&E: Total long-term debt (3) $ 8,950 $ — $ 7,760 $ — $ 7,760 SoCalGas: Total long-term debt (4) $ 7,359 $ — $ 6,880 $ — $ 6,880 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 December 31, 2024 and 2023, respectively. Excludes unamortized transaction costs of $3 and $4 at December 31, 2024 and 2023, respectively. (2) After the effects of interest rate swaps. Before reductions of unamortized discount and debt issuance costs of $382 and $322 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $1,315 and $1,340 at December 31, 2024 and 2023, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $95 and $89 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $1,205 and $1,233 at December 31, 2024 and 2023, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $65 and $55 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $110 and $107 at December 31, 2024 and 2023, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 14.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2024
Equity [Abstract]
Preferred Stock	PREFERRED STOCK Sempra and SDG&E are authorized to issue up to 50,000,000 and 45,000,000 shares of preferred stock, respectively. At December 31, 2024 and 2023, SDG&E had no preferred stock outstanding. The rights, preferences, privileges and restrictions for any new series of preferred stock would be established by each company’s board of directors at the time of issuance. We discuss SoCalGas preferred stock below. 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. SEMPRA SERIES C PREFERRED STOCK At December 31, 2024 and 2023, Sempra had 900,000 shares of 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C (series C preferred stock) outstanding. Liquidation Preference Each share of series C preferred stock has a liquidation preference of $1,000 plus any accumulated and unpaid dividends (whether or not declared) on such share. Redemption at the Option of Sempra The shares of series C preferred stock are perpetual and have no maturity date. However, we may, at our option, redeem the series C preferred stock in whole or in part, from time to time, on any day during the period from and including the July 15 immediately preceding October 15, 2025 and October 15 of every fifth year after 2025 through and including such October 15 at a redemption price in cash equal to $1,000 per share. Additionally, in the event that a credit rating agency then publishing a rating for us makes certain amendments, clarifications or changes to the criteria it uses to assign equity credit to securities such as the series C preferred stock (Ratings Event), we may redeem the series C preferred stock, in whole but not in part, at any time within 120 days after the conclusion of any review or appeal process instituted by us following the occurrence of the Ratings Event or, if no such review or appeal process is available or sought, the occurrence of such Ratings Event, at a redemption price in cash equal to $1,020 per share (102% of the liquidation preference per share). Dividends Dividends on the series C preferred stock, when, as and if declared by our board of directors or an authorized committee thereof, are payable in cash, on a cumulative basis, semi-annually in arrears. Dividends on the series C preferred stock will be cumulative whether or not: ▪ we have earnings; ▪ the payment of such dividends is then permitted under California law; ▪ such dividends are authorized or declared; and ▪ any agreements to which we are a party prohibit the current payment of dividends, including any agreement relating to our indebtedness. We accrue dividends on the series C preferred stock on a monthly basis. The dividend rate from and including June 19, 2020 to, but excluding, October 15, 2025 is 4.875% per annum of the $1,000 liquidation preference per share. The dividend rate will reset on October 15, 2025 and on October 15 of every fifth year after 2025 and, for each five-year period following such reset dates, will be a per annum rate equal to the Five-year U.S. Treasury Rate (as defined in the certificate of determination of preferences of the series C preferred stock) as of the second business day prior to such reset date, plus a spread of 4.550%, of the $1,000 liquidation preference per share. Voting Rights The holders of series C preferred stock do not have any voting rights, except with respect to any authorization, creation or increase in the authorized amount of any class or series of capital stock ranking senior to the series C preferred stock, certain amendments to the terms of the series C preferred stock, in certain other limited circumstances and as otherwise specifically required by California law. In addition, whenever dividends on any shares of series C preferred stock have not been declared and paid or have been declared but not paid for three or more dividend periods, whether or not consecutive, the authorized number of directors on our board of directors will automatically be increased by two and the holders of the series C preferred stock, voting together as a single class with holders of any and all other outstanding series of preferred stock of equal rank having similar voting rights, will be entitled to elect two directors who satisfy certain requirements to fill such two newly created directorships. This voting right will terminate when all accumulated and unpaid dividends on the series C preferred stock have been paid in full and, upon such termination and the termination of the same voting rights of all other holders of outstanding series of preferred stock that have such voting rights, the term of office of each director elected pursuant to such rights will terminate and the authorized number of directors will automatically decrease by two, subject to the revesting of such rights in the event of each subsequent nonpayment. Ranking The series C preferred stock ranks, with respect to dividend rights and distribution rights upon our liquidation, winding-up or dissolution: ▪ senior to our common stock and each other class or series of our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ on parity with each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks on parity with the series C preferred stock; ▪ junior to each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks senior to the series C preferred stock; ▪ junior to our existing and future indebtedness and other liabilities; and ▪ structurally subordinated to all existing and future indebtedness and other liabilities of our subsidiaries and capital stock of our subsidiaries held by third parties. SOCALGAS PREFERRED STOCK SoCalGas is authorized to issue up to an aggregate of 11,000,000 shares of preferred stock, series preferred stock and preference stock. The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2024 2023 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2) (2) Sempra - Total preferred stock of subsidiary $ 20 $ 20 None of SoCalGas’ outstanding preferred stock is callable, and no shares are subject to mandatory redemption. All outstanding shares have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share plus any unpaid dividends. In addition to the outstanding preferred stock above, SoCalGas’ articles of incorporation authorize 5,000,000 shares of series preferred stock and 5,000,000 shares of preference stock, both without par value and with cumulative preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock and series preferred stock. Other rights and privileges of any new series of such stock would be established by the SoCalGas board of directors at the time of issuance. The preferred stock at SoCalGas is presented at Sempra as NCI. Sempra records charges against income related to NCI for preferred dividends declared by SoCalGas.

SEMPRA - EQUITY AND EARNINGS PE

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE	12 Months Ended
	Dec. 31, 2024
Earnings Per Share [Abstract]
SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE	SEMPRA – EQUITY AND EARNINGS PER COMMON SHARE COMMON STOCK We are authorized to issue 1,125,000,000 shares of Sempra’s no par value common stock. The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY 2024 2023 2022 Sempra: Common shares outstanding, January 1 631,431,732 628,669,356 633,839,564 Shares issued under forward sale agreements 17,142,858 — — Shares issued to underwriters to cover overallotments — 2,099,152 — RSUs vesting (1) 1,320,561 941,910 914,444 Stock options exercised 143,944 — 81,260 Common stock investment plan (2) 1,151,877 1,730 — Issuance of RSUs held in our Deferred Compensation Plan 128,207 132,178 130,026 Shares repurchased (3) (689,303) (412,594) (6,295,938) Common shares outstanding, December 31 650,629,876 631,431,732 628,669,356 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) Includes shares repurchased under repurchase programs and shares withheld from LTIP participants and individuals exercising stock options in 2024 to satisfy minimum statutory tax withholding requirements. COMMON STOCK OFFERINGS ATM Program In November 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. At December 31, 2024, approximately $2.7 billion of common stock remained available for sale under the ATM program, which reflects the forward sale agreement that we describe below. November 2024 Forward Sale Agreement In November 2024, we entered into a forward sale agreement under the ATM program with Bank of America, N.A. as forward purchaser for the sale of 2,909,274 shares of Sempra common stock. The shares offered pursuant to the forward sale agreement were borrowed by the forward purchaser and therefore are not newly issued shares. We did not initially receive any proceeds from the sale of shares pursuant to the forward sale agreement. At December 31, 2024, a total of 2,909,274 shares of Sempra common stock remain subject to future settlement under this forward sale agreement, which may be settled on one or more dates specified by us occurring no later than June 30, 2026, which is the final settlement date under the agreement. At the initial forward price of $92.1546 per share, we expect that the net proceeds from the full physical settlement of the forward sale agreement would be approximately $268 million (net of sales commissions of approximately $2 million, but before deducting equity issuance costs, and subject to certain adjustments pursuant to the forward sale agreements). Although we expect to settle the forward sale agreement 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 agreement. The forward sale agreement is also subject to acceleration by the forward purchaser upon the occurrence of certain events. November 2023 Common Stock Offering and 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 with an affiliate of Morgan Stanley & Co. LLC and an affiliate of Citigroup Global Markets Inc. (the November 2023 forward purchasers). The shares offered pursuant to the forward sale agreements were borrowed by the underwriters and therefore are not newly issued shares. The underwriters of the offering partially exercised the option we granted them and purchased 2,099,152 shares of common stock directly from us solely to cover overallotments. We received net proceeds of $144 million (net of underwriting discounts and equity issuance costs of $3 million) from the sale of shares to cover overallotments. We did not initially receive any proceeds from the sale of shares pursuant to the forward sale agreements. We used the net proceeds from the sale of the overallotment shares to fund working capital and for other general corporate purposes, including to partly finance our long-term capital plan and to repay commercial paper and other indebtedness. In December 2024, upon full physical settlement of the forward sale agreements from our November 2023 offering, we received net proceeds of $1.2 billion (net of underwriting discounts and equity issuance costs of $20 million) from the issuance of 17,142,858 shares of Sempra common stock at a forward price of $69.2195 per share. We expect to use the net proceeds from our common stock issued pursuant to the forward sale agreements to fund working capital and for other general corporate purposes, including to partly finance our long-term capital plan and to repay commercial paper and other indebtedness. COMMON STOCK REPURCHASES On July 6, 2020, our board of directors authorized the repurchase of shares of our common stock at any time and from time to time in an aggregate amount not to exceed the lesser of $2.0 billion or amounts spent to purchase no more than 25,000,000 shares. On January 11, 2022, we entered into an ASR program under which we prepaid $200 million to repurchase shares of our common stock in a share forward transaction. A total of 2,945,512 shares were purchased under this program at an average price of $67.90 per share. The total number of shares purchased was determined by dividing the $200 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of January 12, 2022 through February 11, 2022, minus a fixed discount. The ASR program was completed on February 11, 2022. On April 6, 2022, we entered into an ASR program under which we prepaid $250 million to repurchase shares of our common stock in a share forward transaction. A total of 2,943,914 shares were purchased under this program at an average price of $84.92 per share. The total number of shares purchased was determined by dividing the $250 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of April 7, 2022 through April 25, 2022, minus a fixed discount. The ASR program was completed on April 25, 2022. As of February 25, 2025, a maximum of $1.25 billion and no more than 19,632,529 shares may yet be purchased under the July 6, 2020 repurchase authorization. In 2024, 2023 and 2022, we withheld 689,303 shares for $43 million, 412,594 shares for $32 million and 406,512 shares for $28 million, respectively, of our common stock that would otherwise be issued to LTIP participants and individuals exercising stock options in 2024 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. The repurchases do not fall under the July 6, 2020 repurchase authorization. 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) Years ended December 31, 2023 2022 Sempra: Net income attributable to Sempra $ 3,075 $ 2,139 Transfers (to) from NCI: (Decrease) increase in shareholders’ equity for sales of NCI (49) 710 Net transfers (to) from NCI (49) 710 Change from net income attributable to Sempra and transfers (to) from NCI $ 3,026 $ 2,849 SI Partners Sale of NCI to ADIA In June 2022, Sempra and ADIA consummated the transaction contemplated under a purchase and sale agreement dated December 21, 2021 (the ADIA Purchase Agreement). Pursuant to the ADIA Purchase Agreement, ADIA acquired Class A Units representing a 10% NCI in SI Partners for a purchase price of $1.7 billion, including post-closing adjustments. As a result of this sale to ADIA, we recorded a $709 million increase in equity held by NCI and an increase in Sempra’s shareholders’ equity of $710 million, net of $12 million in transaction costs and $300 million income tax expense. Transaction costs include $10 million paid to ADIA for reimbursement of certain expenses that ADIA incurred in connection with closing the transaction. Sale of NCI to KKR Pinnacle In connection with the October 2021 sale of NCI to KKR Pinnacle, KKR Pinnacle was entitled to a $200 million credit from Sempra to be applied to capital calls once an LNG project reached a positive final investment decision and met certain projected internal rates of return. In 2023, KKR Pinnacle used $200 million of this credit 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, a subsidiary of SI Partners completed the sale of a 60% interest in an SI Partners subsidiary (resulting in a 42% NCI in the PA LNG Phase 1 project) to KKR Denali for aggregate cash consideration of $976 million, including post-closing adjustments. As a result of this sale, we recorded a $1.0 billion increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $61 million, including $11 million in transaction costs and net of a $23 million tax benefit. SI Partners’ and KKR Denali’s subsidiaries 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, a subsidiary of SI Partners completed the sale of a 30% interest in an SI Partners subsidiary (resulting in a 30% NCI in the PA LNG Phase 1 project) to an affiliate of ConocoPhillips for aggregate cash consideration of $254 million, including post-closing adjustments. 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. SI Partners’ subsidiary 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 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 December 31, 2024, an aggregate amount of $2.7 billion has been paid by SI Partners’ 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) Years ended December 31, 2024 2023 2022 Sempra: Numerator: Earnings attributable to common shares $ 2,817 $ 3,030 $ 2,094 Denominator: Weighted-average common shares outstanding for basic EPS (1) 633,795 630,296 630,318 Dilutive effect of stock options and RSUs (2) 2,112 2,341 2,439 Dilutive effect of common shares sold forward 2,036 96 — Weighted-average common shares outstanding for diluted EPS 637,943 632,733 632,757 EPS: Basic $ 4.44 $ 4.81 $ 3.32 Diluted $ 4.42 $ 4.79 $ 3.31 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 617 in 2024, 717 in 2023 and 805 in 2022. 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 13, 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 2024, 2023 and 2022 excludes potentially dilutive shares related to stock options and RSUs of 747,724, 502,942 and 173,064, 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 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.

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Share-based Compensation	SHARE-BASED COMPENSATION SEMPRA EQUITY COMPENSATION PLANS Sempra has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra. The plans permit a wide variety of share-based awards, including: ▪ nonqualified stock options ▪ incentive stock options ▪ restricted stock awards ▪ restricted stock units ▪ stock appreciation rights ▪ performance awards ▪ stock payments ▪ dividend equivalents Eligible employees, including those from SDG&E and SoCalGas, participate in Sempra’s share-based compensation plans as a component of their compensation package. In the three years ended December 31, 2024, Sempra had the following types of equity awards outstanding: ▪ Nonqualified Stock Options : Options to purchase common stock have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a three ▪ Performance-Based Restricted Stock Units : These RSU awards generally vest in Sempra common stock at the end of three ▪ Service-Based Restricted Stock Units: RSUs may also be service-based; these generally vest ratably over three For awards that would otherwise be forfeited upon termination of employment, the Compensation and Talent Development Committee of Sempra’s board of directors may waive the forfeiture requirement and, with respect to options and service-based RSUs, may accelerate vesting. Awards are also subject to accelerated vesting under certain circumstances upon a change in control under the applicable LTIP, in accordance with severance pay agreements or to the extent otherwise required by the terms of the applicable award. Dividend equivalents on shares subject to RSUs are reinvested to purchase additional common shares that become subject to the same vesting conditions as the RSUs to which the dividends relate. SHARE-BASED AWARDS AND COMPENSATION EXPENSE At December 31, 2024, 15,400,000 common shares were authorized, and 7,628,467 common shares were available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three Sempra subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra plans’ corporate staff costs. Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Share-based compensation expense, before income taxes (1) $ 77 $ 71 $ 61 Income tax benefit (1) (9) (9) (17) $ 68 $ 62 $ 44 Capitalized share-based compensation cost $ 13 $ 12 $ 11 Excess income tax (benefit) deficiency (9) (6) (3) SDG&E: Share-based compensation expense, before income taxes $ 12 $ 13 $ 11 Income tax benefit (2) (2) (3) $ 10 $ 11 $ 8 Capitalized share-based compensation cost $ 7 $ 7 $ 6 Excess income tax (benefit) deficiency (1) (1) — SoCalGas: Share-based compensation expense, before income taxes $ 20 $ 18 $ 17 Income tax benefit (4) (3) (5) $ 16 $ 15 $ 12 Capitalized share-based compensation cost $ 6 $ 5 $ 5 Excess income tax (benefit) deficiency (2) (1) — (1) Includes activity of awards issued from the IEnova 2013 LTIP, which settled in cash upon vesting based on the price of IEnova’s common stock. SEMPRA NONQUALIFIED STOCK OPTIONS We use a Black-Scholes option-pricing model to estimate the fair value of each nonqualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on a blend of the historical and implied volatility of Sempra’s common stock price. The average expected term for options is based on the vesting schedule, contractual term of the option, expected employee exercise and post-termination behavior. The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected term estimated at the date of the grant. In 2024, 2023 and 2022, Sempra’s board of directors granted 414,812, 326,574 and 439,796 nonqualified stock options, respectively, that become exercisable over a three KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Years ended December 31, 2024 2023 2022 Sempra: Stock price volatility 26.49 % 27.35 % 26.08 % Expected term 5.36 years 5.36 years 5.36 years Risk-free rate of return 3.90 % 3.89 % 1.40 % Annual dividend yield 3.14 % 2.98 % 3.33 % The following table shows a summary of nonqualified stock options at December 31, 2024 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value Sempra: Outstanding at January 1, 2024 1,759,798 $ 65.99 Granted 414,812 $ 75.82 Exercised (23,713) $ 62.87 Withheld related to net settlement (120,231) $ 62.87 Outstanding at December 31, 2024 2,030,666 $ 68.22 6.78 $ 40 Vested or expected to vest at December 31, 2024 2,030,666 $ 68.22 6.78 $ 40 Exercisable at December 31, 2024 1,251,544 $ 64.45 5.81 $ 29 The aggregate intrinsic value at December 31, 2024 is the total of the difference between Sempra’s closing common stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for nonqualified stock options exercised was: ▪ $4.4 million in 2024 ▪ zero in 2023 ▪ $1.7 million in 2022 We expect a negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2024 to be recognized over a weighted-average period of 0.6 years. The weighted-average exercise price for nonqualified stock options granted in 2023 and 2022 was $76.86 and $66.00, respectively. We received cash of $4 million from stock option exercises in 2022. SEMPRA RESTRICTED STOCK UNITS We use Sempra’s common stock price at the grant date to estimate the fair value of our service-based RSUs and our RSUs that vest based on the compound annual growth rate of Sempra’s EPS. We use a Monte-Carlo simulation model to estimate the fair value of our RSUs that vest based on Sempra’s total return to shareholders. Our determination of fair value is affected by the historical volatility of the common stock price for Sempra and its peer group companies. The valuation also is affected by the risk-free rates of return and a number of other variables. Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2024 2023 2022 Sempra: Stock price volatility 21.27 % 35.31 % 32.82 % Risk-free rate of return 4.06 % 4.13 % 1.05 % The following table shows a summary of RSUs at December 31, 2024 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based Service-based Units Weighted- average Units Weighted- average grant-date fair value Sempra: Nonvested at January 1, 2024 1,829,984 $ 74.46 524,969 $ 70.63 Granted 721,049 $ 75.70 321,576 $ 75.86 Vested (571,322) $ 66.52 (281,494) $ 68.68 Forfeited (73,987) $ 76.78 (21,963) $ 88.74 Nonvested at December 31, 2024 (1) 1,905,724 $ 77.22 543,088 $ 74.55 Expected to vest at December 31, 2024 1,865,938 $ 77.19 525,029 $ 74.49 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra exceeds target performance conditions. In 2024, 2023 and 2022, the total fair value of RSU shares vested during the year was $57 million, $52 million and $54 million, respectively. We expect $43 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2024 to be recognized over a weighted-average period of 1.80 years. The weighted-average per-share fair values for performance-based RSUs granted were $82.64 and $73.47 in 2023 and 2022, respectively. The weighted-average per-share fair values for service-based RSUs granted were $76.76 and $66.32 in 2023 and 2022, respectively.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
SAN ONOFRE NUCLEAR GENERATING STATION	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until 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) AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Fixed-price contracts and other derivatives $ 53 $ 215 $ 11 $ 14 $ 42 $ 201 Deferred income taxes recoverable in rates 1,689 1,142 802 626 817 430 Pension and PBOP plan obligations (458) (212) (2) 48 (456) (260) Employee benefit costs 19 24 3 3 16 21 Removal obligations (3,295) (3,082) (2,676) (2,468) (619) (614) Environmental costs 149 139 115 105 34 34 Sunrise Powerlink fire mitigation 124 124 124 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (313) (233) (313) (233) — — Commodity – gas, including transportation (47) (259) 86 52 (133) (311) Safety and reliability 820 959 227 207 593 752 Public purpose programs (439) (273) (219) (144) (220) (129) 2024 GRC retroactive impacts 631 — 277 — 354 — Wildfire mitigation plan 808 685 808 685 — — Liability insurance premium (24) 113 (15) 90 (9) 23 Other balancing accounts 158 373 (51) (152) 209 525 Other regulatory assets (liabilities), net (2) 164 (10) 87 49 79 (58) Total $ 39 $ (295) $ (736) $ (994) $ 707 $ 614 (1) At December 31, 2024 and 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $1,731 and $1,913, respectively, for SDG&E was $873 and $950, respectively, and for SoCalGas was $858 and $963, respectively. (2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. Regulatory Assets Not Earning a Return ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. The related amounts are recovered in rates once these contracts are settled, generally within four years. ▪ Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Infrastructure expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include excess deferred income taxes resulting from statutory income tax rate changes and certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 7. ▪ Regulatory assets/liabilities related to pension and PBOP plan obligations are offset by corresponding liabilities/assets. The assets are recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 45-year period. Regulatory Assets Earning a Return ▪ Over- and undercollected regulatory balancing accounts and other regulatory assets, net, reflect the difference between customer billings and recorded or CPUC-authorized amounts. Depreciation, taxes and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. The adopted revenue requirements in the 2024 GRC FD were placed into rates on February 1, 2025 and the incremental revenue requirements associated with the period from January 1, 2024 through January 31, 2025 are being recovered in rates over an 18-month period that began on February 1, 2025. SDG&E and SoCalGas periodically make requests to the CPUC to true up their revenue requirement for amounts accumulated in the regulatory balancing accounts and in other regulatory assets, net. The CPUC may impose various review procedures before authorizing recovery or refund of amounts accumulated for authorized programs, including limitations on the program’s total cost, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in delays or disallowances of recovery from customers. Amortization expense on certain regulatory assets for the years ended December 31, 2024, 2023 and 2022 was $14 million, $12 million and $11 million, respectively, at Sempra, $7 million, $6 million and $5 million, respectively, at SDG&E, and $7 million, $6 million and $6 million, respectively, at SoCalGas. CPUC GRC The CPUC uses GRCs to set revenues to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. In December 2024, the CPUC approved an FD in the 2024 GRC for SDG&E and SoCalGas that authorizes SDG&E’s and SoCalGas’ revenue requirements for 2024 and attrition year adjustments for 2025 through 2027, inclusively. The GRC FD adopts a 2024 revenue requirement of $2,699 million for SDG&E’s combined operations ($2,193 million for its electric operations and $506 million for its natural gas operations). SDG&E’s authorized 2024 combined revenue requirement represents an increase of $189 million (7.5%) over its authorized 2023 combined revenue requirement. In connection with SDG&E’s election to change its tax accounting method for gas repairs expenditures, the 2024 combined revenue requirement increase is net of $68 million of income tax benefits for 2023 and 2024 to be flowed through to customers. The GRC FD also specifies an increase in SDG&E’s 2025, 2026, and 2027 combined revenue requirements of $147 million (5.45%), $119 million (4.17%) and $122 million (4.11%), respectively, over the preceding year’s combined revenue requirement. The 2025, 2026 and 2027 revenue requirements will be updated to implement a previously authorized change in the cost of capital, which we describe below, that adjusted SDG&E’s rate of return to 7.45%. The GRC FD adopts a 2024 revenue requirement of $3,806 million for SoCalGas. SoCalGas’ authorized 2024 revenue requirement represents an increase of $324 million (9.3%) over its authorized 2023 revenue requirement. In connection with SoCalGas’ election to change its tax accounting method for gas repairs expenditures, the 2024 revenue requirement increase is net of $202 million of income tax benefits for 2023 and 2024 to be flowed through to customers. The GRC FD also specifies an increase in SoCalGas’ 2025, 2026, and 2027 revenue requirements of $190 million (5.00%), $116 million (2.91%) and $120 million (2.92%), respectively, over the preceding year’s revenue requirement. The 2025, 2026 and 2027 revenue requirements will be updated to implement a previously authorized change in the cost of capital, which we describe below, that adjusted SoCalGas’ rate of return to 7.49%. The GRC provides SDG&E and SoCalGas with numerous mechanisms to seek cost recovery of specified projects and programs. We expect that the requests for cost recovery of these projects and programs, which remain subject to CPUC approval, will result in additional amounts of authorized revenue requirement that are not included in the amounts described above. Since the GRC FD is effective retroactive to January 1, 2024, SDG&E and SoCalGas recorded the retroactive impacts in the fourth quarter of 2024. 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 and not addressed in the 2024 GRC FD. SDG&E expects to receive a proposed decision for its Track 2 request in the first half of 2025. Revenue requirements associated with the Track 2 request have been recorded in a regulatory account. In February 2024, the CPUC approved an interim cost recovery mechanism that permits 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 wildfire mitigation plan costs incurred in 2023. The GRC FD expanded the scope of the Track 3 filing to include review of SoCalGas’ and SDG&E’s Pipeline Safety Enhancement Plan costs incurred from 2015 to 2020, inclusively. CPUC COST OF CAPITAL A CPUC cost of capital proceeding every three years determines a utility’s authorized capital structure and authorized return on rate base. The CCM applies in the interim years and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered in each measurement period, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.00% for the measurement period. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application to have its cost of capital determined in lieu of the CCM in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. The CPUC-approved cost of capital for SDG&E and SoCalGas that became effective on January 1, 2020 remained in effect through December 31, 2022. The CPUC subsequently approved the 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. The CCM was triggered for SDG&E and SoCalGas for the measurement period ending September 30, 2023, and in December 2023, the CPUC approved updated authorized rates of return effective January 1, 2024. 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 an FD to modify the CCM. The FD updates the upward or downward adjustment to authorized ROE, if the CCM is triggered, from 50% to 20% of the change in the benchmark rate during the measurement period. The FD adopted 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. The following table summarizes the cost of capital for SDG&E and SoCalGas. The authorized weighting remained unchanged for each of the years presented. AUTHORIZED COST OF CAPITAL Authorized weighting 2022 2023 2024 2025 2022 2023 (1) 2024 2025 Return on rate base Weighted return on rate base SDG&E: Long-Term Debt 45.25 % 4.59 % 4.05 % 4.34 % 4.34 % 2.08 % 1.83 % 1.96 % 1.96 % Preferred Equity 2.75 6.22 6.22 6.22 6.22 0.17 0.17 0.17 0.17 Common Equity 52.00 10.20 9.95 10.65 10.23 5.30 5.17 5.54 5.32 100.00 % 7.55 % 7.18 % 7.67 % 7.45 % SoCalGas: Long-Term Debt 45.60 % 4.23 % 4.07 % 4.54 % 4.63 % 1.93 % 1.86 % 2.07 % 2.11 % Preferred Equity 2.40 6.00 6.00 6.00 6.00 0.14 0.14 0.14 0.14 Common Equity 52.00 10.05 9.80 10.50 10.08 5.23 5.10 5.46 5.24 100.00 % 7.30 % 7.10 % 7.67 % 7.49 % (1) Total weighted return on rate base for SDG&E does not sum due to rounding differences. 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. TO5 Settlement SDG&E’s authorized TO5 settlement provided for an ROE of 10.60%, consisting of a base ROE of 10.10% plus the California ISO adder. In December 2024, the FERC issued an order, which SDG&E has appealed, finding that SDG&E is not eligible for the California ISO adder and that the TO5 adder refund provision has been triggered, requiring SDG&E to refund customers the California ISO adder retroactively from June 1, 2019. As a result of the FERC order, SDG&E recorded a charge of $120 million ($89 million after tax) with $94 million in Electric Revenues and $26 million in Other Income, Net, on the SDG&E and Sempra Consolidated Statements of Operations in the year ended December 31, 2024. TO6 Filing 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, requested to be effective January 1, 2025, and 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% plus the California ISO adder, for a total ROE of 12.25%. In December 2024, the FERC accepted SDG&E’s TO6 filing but suspended the effective date to June 1, 2025 and disallowed the inclusion of the California ISO adder, which SDG&E has appealed. SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra’s and SDG&E’s Consolidated Statements of Operations. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to 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 an ISFSI and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In January 2025, the CPUC granted SDG&E authorization to access NDT funds of up to $66 million for forecasted 2025 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 10. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated December 31, 2024 Short-term investments, primarily cash equivalents $ 10 $ — $ — $ 10 Equity securities 78 223 (3) 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 67 1 (1) 67 Municipal bonds (2) 295 1 (9) 287 Other securities (3) 234 2 (8) 228 Total debt securities 596 4 (18) 582 Receivables (payables), net (15) — — (15) Total $ 669 $ 227 $ (21) $ 875 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 2025-2062. (3) Maturity dates are 2025-2072. The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Proceeds from sales $ 874 $ 592 $ 639 Gross realized gains 57 27 18 Gross realized losses 10 14 20 Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. ASSET RETIREMENT OBLIGATION The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $471 million at December 31, 2024 and is based on a cost study prepared in 2024, which is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $89 million in 2025, $57 million in 2026, $37 million in 2027, $25 million in 2028, $11 million in 2029, and $870 million thereafter. U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC. The ISFSI will operate until 2054, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018, which is pending approval. Additionally, in July 2024, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from August 2018 through December 2021, which is pending approval. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $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	12 Months Ended
	Dec. 31, 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 December 31, 2024, loss contingency accruals for legal matters that are probable and estimable were $41 million for Sempra, including $26 million for SoCalGas. We discuss our policy regarding accrual of legal fees in Note 1. 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. In November 2024, the Court of Appeal affirmed the trial court judgment in favor of SDG&E and the City of San Diego. The plaintiff in that case has further appealed. 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 February 19, 2025, 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. SoCalGas recorded total charges of $259 million ($199 million after tax) in the year ended December 31, 2022 in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Consolidated Statements of Operations related to the litigation and regulatory proceedings associated with the Leak. Aliso Canyon Natural Gas Storage Facility Regulatory Proceeding – Resolved 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. In December 2024, the CPUC approved an FD in the SB 380 OII finding that the Aliso Canyon natural gas storage facility is currently necessary for natural gas and electric reliability and affordable rates and closed the OII. Among other things, and subject to future CPUC biennial reviews and potential additional proceedings, the FD authorizes the Aliso Canyon natural gas storage facility to continue operating and sets the maximum working natural gas storage level at 68.6 bcf. 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. In November 2024, the plaintiff withdrew the lawsuit and the case was dismissed, definitively resolving this matter. ▪ 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. In November 2024, the plaintiff filed 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. In February 2025, the Supreme Court of Texas adopted Port Arthur LNG’s interpretation of the standard. Port Arthur LNG continues to litigate this matter before the U.S. Court of Appeals for the Fifth Circuit, which will apply the standard adopted by the Supreme Court of Texas. The 2022 Permit is effective during the pending litigation. 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 LLP – Resolved As we discuss in Note 5, Sempra held an equity method investment in RBS Sempra Commodities LLP, a limited liability partnership that was substantially liquidated in 2024. 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. Trial on the matter was held in 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies. The Defendants appealed and, in May 2021, the Court of Appeal set aside the High Court of Justice’s decision and ordered a retrial. In July 2022, the Supreme Court of the U.K. denied the Liquidating Companies application for permission to appeal the Court of Appeal’s decision. In January 2024, the parties settled the Liquidating Companies’ claim against the Defendants, which fully resolved these matters. 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 A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract. Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, aircraft, power generating facilities and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for refined products terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately. Lessee Accounting We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, aircraft, tugboats, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities. Some of our leases include options to extend the lease terms for up to 25 years, or to terminate the lease within one year. Our lease liabilities and ROU assets are based on lease terms that may include such options when it is reasonably certain that we will exercise the option. Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. Certain of our leases contain escalation clauses requiring annual increases in rent ranging from 2% to 5% or based on the Consumer Price Index. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year. Variable lease payments that are based on an index or rate are included in the initial measurement of our lease liability and ROU asset based on the index or rate at lease commencement and are not remeasured because of changes to the index or rate. Rather, changes to the index or rate are treated as variable lease payments and recognized in the period in which the obligation for those payments is incurred. Similarly, PPAs for the purchase of renewable energy at SDG&E require lease payments based on a stated rate per MWh produced by the facilities, and we are required to purchase substantially all the output from the facilities. SDG&E is required to pay additional amounts for capacity charges and actual purchases of energy that exceed the minimum energy commitments. Under these contracts, we do not recognize a lease liability or ROU asset for leases for which there are no fixed lease payments. Rather, these variable lease payments are recognized separately as variable lease costs. SDG&E estimates these variable lease payments to be $296 million in 2025, $290 million in 2026, $289 million in 2027, $290 million in 2028, $289 million in 2029 and $1.9 billion thereafter. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record a corresponding ROU asset, initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. We test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets. For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. SDG&E and SoCalGas recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. SDG&E and SoCalGas recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. Our leases do not contain any material residual value guarantees, restrictions or covenants. Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below. LESSEE INFORMATION ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) Sempra SDG&E SoCalGas December 31, 2024 2023 2024 2023 2024 2023 ROU assets: Operating leases: ROU assets $ 1,177 $ 723 $ 795 $ 368 $ 18 $ 29 Finance leases: PP&E 1,626 1,585 1,426 1,412 200 173 Accumulated depreciation (311) (246) (221) (179) (90) (66) PP&E, net 1,315 1,339 1,205 1,233 110 107 Total ROU assets $ 2,492 $ 2,062 $ 2,000 $ 1,601 $ 128 $ 136 Lease liabilities: Operating leases: Other current liabilities (1) $ 91 $ 70 $ 68 $ 50 $ 8 $ 10 Deferred credits and other (2) 1,019 599 734 325 9 18 1,110 669 802 375 17 28 Finance leases: Current portion of long-term debt and finance leases 65 64 42 41 23 23 Long-term debt and finance leases 1,250 1,276 1,163 1,192 87 84 1,315 1,340 1,205 1,233 110 107 Total lease liabilities $ 2,425 $ 2,009 $ 2,007 $ 1,608 $ 127 $ 135 Weighted-average remaining lease term (in years): Operating leases 13 13 12 10 2 3 Finance leases 14 15 15 16 6 6 Weighted-average discount rate: Operating leases (3) 6.10 % 6.64 % 5.06 % 4.52 % 4.70 % 4.54 % Finance leases 13.71 % 13.80 % 14.11 % 14.18 % 5.35 % 4.94 % (1) Includes $43 and $18 related to PPAs at December 31, 2024 and 2023, respectively, at both Sempra and SDG&E. (2) Includes $627 and $208 related to PPAs at December 31, 2024 and 2023, respectively, at both Sempra and SDG&E. (3) Weighted-average discount rate related to PPAs at December 31, 2024 and 2023 is 5.04% and 4.19%, respectively, at both Sempra and SDG&E. Weighted-average discount rate related to all other operating leases at December 31, 2024 and 2023 is 7.41% and 7.57%, respectively, at Sempra and 5.23% and 5.06%, respectively, at SDG&E. The components of lease costs were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 2024 2023 2022 Operating lease costs (2) $ 118 $ 99 $ 83 $ 71 $ 53 $ 45 $ 12 $ 13 $ 18 Finance lease costs: Amortization of ROU assets (3) 65 60 48 42 40 33 23 20 15 Interest on lease liabilities 178 182 184 173 177 181 6 5 2 Total finance lease costs 243 242 232 215 217 214 29 25 17 Short-term lease costs (4) 9 9 3 8 8 2 — — — Variable lease costs (4) 472 458 411 460 447 399 10 10 11 Total lease costs $ 842 $ 808 $ 729 $ 754 $ 725 $ 660 $ 51 $ 48 $ 46 (1) Includes costs capitalized in PP&E. (2) Includes $37, $21, and $10 related to PPAs in 2024, 2023 and 2022, respectively, at both Sempra and SDG&E. (3) Included in O&M, except for $30, $29 and $25 at Sempra and $29, $28 and $24 at SDG&E in 2024, 2023 and 2022, respectively, and $1 at SoCalGas in each of 2024, 2023 and 2022, which is included in Depreciation and Amortization Expense. (4) Short-term leases with variable lease costs are recorded and presented as variable lease costs. Cash paid for amounts included in the measurement of lease liabilities and supplemental noncash information were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 2024 2023 2022 Operating activities: Cash paid for operating leases $ 112 $ 85 $ 88 $ 70 $ 46 $ 45 $ 12 $ 13 $ 18 Cash paid for finance leases 163 167 169 158 162 166 6 5 2 Financing activities: Cash paid for finance leases 66 60 48 42 40 33 24 20 15 Increase in operating lease obligations for ROU assets 520 143 142 474 134 134 — — 1 Increase in finance lease obligations for investment in PP&E 41 57 57 14 17 16 27 40 41 The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities at December 31, 2024: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) Sempra SDG&E SoCalGas Operating leases (1) Finance leases Operating leases (1) Finance leases (2) Operating leases Finance leases 2025 $ 142 $ 224 $ 97 $ 196 $ 10 $ 28 2026 142 220 98 195 7 25 2027 134 218 97 194 — 24 2028 128 212 92 193 — 19 2029 124 204 89 190 — 14 Thereafter 966 1,745 571 1,727 — 18 Total undiscounted lease payments 1,636 2,823 1,044 2,695 17 128 Less: imputed interest (526) (1,508) (242) (1,490) — (18) Total lease liabilities 1,110 1,315 802 1,205 17 110 Less: current lease liabilities (91) (65) (68) (42) (8) (23) Long-term lease liabilities $ 1,019 $ 1,250 $ 734 $ 1,163 $ 9 $ 87 (1) Includes $76 in 2025, $75 in 2026, $76 in 2027, $75 in each of 2028 and 2029, and $525 thereafter related to PPAs. (2) Substantially all amounts are related to PPAs. Leases That Have Not Yet Commenced SDG&E has entered into four PPAs, of which SDG&E expects two will commence in 2025 and two will commence in 2026. SDG&E expects the future minimum lease payments to be $16 million in 2025, $41 million in 2026, $43 million each of 2027 through 2029 and $459 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 2024, SoCalGas prepaid $1 million and expects the future minimum lease payments to be $8 million in 2028, $9 million in 2029 and $134 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 each of 2028 and 2029 and $198 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, LPG storage facilities, a rail facility and refined products terminals, which we account for as operating or sales-type leases. These leases expire at various dates from 2025 through 2042. Over the lease term, we monitor the underlying assets in operating leases for impairment, and we evaluate the net investment in sales-type leases for expected credit losses. Sempra Infrastructure expects to continue to derive value from the underlying assets associated with its pipelines following the end of their respective lease terms based on the expected remaining useful life, expected market conditions and plans to re-market and re-contract the underlying assets. Generally, we recognize operating lease income on a straight-line basis over the lease term, and sales-type lease income based on the effective interest method over the lease term. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next. In addition to minimum fixed payments, our refined products terminals receive variable lease payments for barrels delivered that exceed minimum delivery requirements. LESSOR INFORMATION (Dollars in millions) December 31, 2024 2023 Sempra – Assets subject to operating leases: Property, plant and equipment: Pipelines and storage $ 1,313 $ 1,304 Refined products terminals 623 621 Other 77 77 Total 2,013 2,002 Accumulated depreciation (605) (539) Property, plant and equipment, net $ 1,408 $ 1,463 December 31, 2024 Sempra – Maturity analysis of lease payments: Operating leases Sales-type leases 2025 $ 318 $ 17 2026 272 9 2027 269 — 2028 268 — 2029 246 — Thereafter 2,324 — Total undiscounted cash flows $ 3,697 26 Less: present value of lease payments (recognized as lease receivable) (1)

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
SEGMENT INFORMATION	SEGMENT INFORMATION SEMPRA Sempra is a California-based holding company whose businesses invest in, develop and operate energy infrastructure in North America and provide electric and gas services to customers. Sempra has the following three operating and reportable segments, which are managed separately based on services provided, geographic location and regulatory framework: ▪ 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, which are regulated public utilities. ▪ Sempra Texas Utilities holds our equity method 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 equity method investment in Sharyland Holdings, which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪ Sempra Infrastructure includes the operating companies of SI Partners, in which Sempra Infrastructure owns a 70% interest, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help provide safe, sustainable and reliable access to cleaner energy in markets in the U.S., Mexico and globally. Sempra’s CODM, who is its chief executive officer, uses segment earnings attributable to common shares predominantly in the annual financial planning process to assess financial performance. Sempra’s CODM prioritizes resource allocation to each segment in a manner that aligns with Sempra’s capital expenditures plan, which is focused on safety, reliability and modernization of its segments’ infrastructure while supporting customer affordability; investing in incremental infrastructure growth projects with attractive risk-adjusted returns; maintaining a strong balance sheet; and returning cash to shareholders. The accounting policies of the segments are consistent with those described in the summary of significant accounting policies in Note 1. Sempra accounts for intersegment sales as if the sales were to third parties, that is, at current market prices. The cost of common services shared by the reportable segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Parent and other allocates depreciation expense to the reportable segments without allocating the related depreciable assets to those reportable segments. Interest income and interest expense are recorded on intersegment loans. We have eliminated intersegment accounts and transactions within Sempra’s consolidated financial statements. Amounts labeled as “Parent and other,” which does not meet the definition of an operating or reportable segment, consist primarily of activities of parent organizations. The following tables present selected information by segment and reconciliations of assets, capital expenditures for PP&E, and earnings attributable to common shares to Sempra’s consolidated totals. SEGMENT INFORMATION (Dollars in millions) December 31, 2024 2023 ASSETS Sempra California $ 56,116 $ 53,430 Sempra Texas Utilities 15,534 14,392 Sempra Infrastructure 22,954 19,430 Segment totals 94,604 87,252 Parent and other 2,622 967 Intersegment eliminations (1) (1,071) (1,038) Total Sempra $ 96,155 $ 87,181 EQUITY METHOD INVESTMENTS Sempra Texas Utilities $ 15,522 $ 14,380 Sempra Infrastructure 2,411 2,129 Segment totals/Total Sempra $ 17,933 $ 16,509 GEOGRAPHIC LOCATION OF PROPERTY, PLANT AND EQUIPMENT, NET United States $ 52,952 $ 46,935 Mexico 8,485 8,024 Rest of the world — 1 Total Sempra $ 61,437 $ 54,960 Years ended December 31, 2024 2023 2022 CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT Sempra California $ 4,753 $ 4,560 $ 4,466 Sempra Infrastructure 3,459 3,832 884 Segment totals 8,212 8,392 5,350 Parent and other 3 5 7 Total Sempra $ 8,215 $ 8,397 $ 5,357 GEOGRAPHIC LOCATION OF REVENUES (2) United States $ 11,623 $ 14,973 $ 13,015 Mexico 1,562 1,747 1,424 Total Sempra $ 13,185 $ 16,720 $ 14,439 (1) Primarily includes an intersegment loan from Sempra Infrastructure to Parent and other related to deferred income taxes. (2) Amounts are based on where the revenue originated, after intersegment eliminations. SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Sempra California Sempra Texas Utilities (1) Sempra Infrastructure Sempra Year ended December 31, 2024 Revenues $ 11,382 $ 1,882 Depreciation and amortization (2,133) (297) Interest income 14 25 Interest expense (2) (848) 243 Income tax (expense) benefit (184) 164 Equity earnings — $ 788 802 Earnings attributable to noncontrolling interests — — (638) Other segment items (3) (6,385) (7) (1,270) Segment earnings attributable to common shares $ 1,846 $ 781 $ 911 $ 3,538 Parent and other (721) Earnings attributable to common shares $ 2,817 Year ended December 31, 2023 Revenues $ 13,761 $ 3,071 Depreciation and amortization (1,937) (281) Interest income 24 43 Interest expense (2) (782) (129) Income tax benefit (expense) 31 (673) Equity earnings — $ 701 740 Earnings attributable to noncontrolling interests — — (543) Other segment items (3) (9,350) (7) (1,351) Segment earnings attributable to common shares $ 1,747 $ 694 $ 877 $ 3,318 Parent and other (288) Earnings attributable to common shares $ 3,030 Year ended December 31, 2022 Revenues $ 12,577 $ 1,919 Depreciation and amortization (1,743) (268) Interest income 11 44 Interest expense (647) (104) Income tax expense (320) (249) Equity earnings — $ 742 756 Earnings attributable to noncontrolling interests — — (146) Other segment items (3) (8,364) (6) (1,642) Segment earnings attributable to common shares $ 1,514 $ 736 $ 310 $ 2,560 Parent and other (466) Earnings attributable to common shares $ 2,094 (1) Substantially all earnings attributable to common shares are from equity earnings. (2) Sempra Infrastructure includes net unrealized gains (losses) from undesignated interest rate swaps related to the PA LNG Phase 1 project. (3) Includes cost of natural gas, cost of electric fuel and purchased power, O&M, Aliso Canyon litigation and regulatory matters, franchise fees and other taxes, other income (expense), net, and preferred dividends for Sempra California; O&M, interest expense, and income tax expense (benefit) for Sempra Texas Utilities related to activities at the holding company; and cost of natural gas, energy-related businesses cost of sales, O&M, franchise fees and other taxes, and other income (expense), net, for Sempra Infrastructure. The following table presents revenues by services by segment, reconciled to Sempra’s consolidated revenues. REVENUES BY SERVICES (Dollars in millions) Sempra California Sempra Infrastructure Sempra Year ended December 31, 2024 Revenues from external customers: Utilities $ 10,985 $ 78 Energy-related businesses — 755 Total revenues from external customers (1) 10,985 833 $ 11,818 Other revenues (2) : Utilities 374 — Energy-related businesses — 993 Total other revenues 374 993 1,367 Intersegment revenues (3) : Utilities 23 — Energy-related businesses — 56 Total intersegment revenues 23 56 79 Segment revenues $ 11,382 $ 1,882 13,264 Intersegment eliminations (79) Revenues $ 13,185 Year ended December 31, 2023 Revenues from external customers: Utilities $ 13,668 $ 87 Energy-related businesses — 1,094 Total revenues from external customers (1) 13,668 1,181 $ 14,849 Other revenues (2) : Utilities 75 — Energy-related businesses — 1,796 Total other revenues 75 1,796 1,871 Intersegment revenues (3) : Utilities 18 — Energy-related businesses — 94 Total intersegment revenues 18 94 112 Segment revenues $ 13,761 $ 3,071 16,832 Intersegment eliminations (112) Revenues $ 16,720 Year ended December 31, 2022 Revenues from external customers: Utilities $ 11,930 $ 89 Energy-related businesses — 1,704 Total revenues from external customers (1) 11,930 1,793 $ 13,723 Other revenues (2) : Utilities 633 — Energy-related businesses — 83 Total other revenues 633 83 716 Intersegment revenues (3) : Utilities 14 — Energy-related businesses — 43 Total intersegment revenues 14 43 57 Segment revenues $ 12,577 $ 1,919 14,496 Intersegment eliminations (57) Revenues $ 14,439 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of Sempra’s total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) See “Transactions with Affiliates” in Note 1 for a description of services provided by one operating segment to another operating segment within Sempra. SDG&E 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 operating and reportable segment. SDG&E’s CODM, who is its chief executive officer, utilizes earnings attributable to common shares to manage the business, assess performance and allocate resources. SDG&E’s CODM allocates resources to support the delivery of safe, reliable and affordable energy to customers. Total assets at SDG&E were $30.8 billion and $29.2 billion at December 31, 2024 and 2023, respectively. The following table presents selected information for SDG&E’s single segment and reconciliation of earnings attributable to common shares. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2024 2023 2022 SDG&E: Revenues from external customers: Electric $ 4,164 $ 4,750 $ 4,687 Natural gas 878 1,204 899 Total revenues from external customers (1) 5,042 5,954 5,586 Other revenues (2) : Electric 149 (401) 109 Natural gas 150 44 143 Total other revenues 299 (357) 252 Total revenues 5,341 5,597 5,838 Depreciation and amortization (1,223) (1,098) (982) Interest income 5 15 5 Interest expense (525) (497) (449) Income tax (expense) benefit (153) 26 (182) Other segment items (3) (2,554) (3,107) (3,315) Earnings attributable to common shares $ 891 $ 936 $ 915 Capital expenditures for property, plant and equipment $ 2,522 $ 2,540 $ 2,473 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of SDG&E’s total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) Includes cost of electric fuel and purchased power, cost of natural gas, O&M, franchise fees and other taxes, and other income (expense), net. SOCALGAS SoCalGas is a regulated public natural gas distribution utility, serving customers throughout most of Southern California and part of central California. SoCalGas has one operating and reportable segment. SoCalGas’ CODM, who is its chief executive officer, utilizes earnings attributable to common shares to manage the business, assess performance and allocate resources. SoCalGas’ CODM allocates resources to support the delivery of safe, reliable and affordable energy to customers. Total assets at SoCalGas were $25.4 billion and $24.3 billion at December 31, 2024 and 2023, respectively. The following table presents selected information for SoCalGas’ single segment and reconciliation of earnings attributable to common shares. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2024 2023 2022 SoCalGas: Natural gas: Revenues from external customers (1) $ 6,134 $ 7,857 $ 6,459 Other revenues (2) 75 432 381 Total revenues 6,209 8,289 6,840 Aliso Canyon litigation and regulatory matters — — (259) Depreciation and amortization (910) (839) (761) Interest income 9 9 6 Interest expense (323) (285) (198) Income tax (expense) benefit (31) 5 (138) Other segment items (3) (3,999) (6,368) (4,891) Earnings attributable to common shares $ 955 $ 811 $ 599 Capital expenditures for property, plant and equipment $ 2,231 $ 2,020 $ 1,993 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of SoCalGas’ total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) Includes cost of natural gas, O&M, franchise fees and other taxes, and other income (expense), net, and preferred dividends.

SCHEDULE I - CONDENSED FINANCIA

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information of Parent	SEMPRA CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2024 2023 2022 Interest income $ 29 $ 31 $ 35 Interest expense (490) (444) (326) Operating expenses (105) (101) (92) Other income (expense), net 25 31 (58) Income tax benefit 165 134 111 Loss before equity in earnings of subsidiaries (376) (349) (330) Equity in earnings of subsidiaries, net of income taxes 3,237 3,423 2,468 Net income 2,861 3,074 2,138 Preferred dividends (44) (44) (44) Earnings $ 2,817 $ 3,030 $ 2,094 Basic EPS: Earnings $ 4.44 $ 4.81 $ 3.32 Weighted-average common shares outstanding 633,795 630,296 630,318 Diluted EPS: Earnings $ 4.42 $ 4.79 $ 3.31 Weighted-average common shares outstanding 637,943 632,733 632,757 See Notes to Condensed Financial Information of Parent. SEMPRA CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2024, 2023 and 2022 Pretax Income tax benefit (expense) Net-of-tax 2024: Net income $ 2,696 $ 165 $ 2,861 Other comprehensive income (loss): Foreign currency translation adjustments (30) — (30) Financial instruments 14 (2) 12 Pension and other postretirement benefits 18 (16) 2 Total other comprehensive income (loss) 2 (18) (16) Comprehensive income $ 2,698 $ 147 $ 2,845 2023: Net income $ 2,940 $ 134 $ 3,074 Other comprehensive income (loss): Foreign currency translation adjustments 23 — 23 Financial instruments 57 (18) 39 Pension and other postretirement benefits (39) 8 (31) Total other comprehensive income 41 (10) 31 Comprehensive income $ 2,981 $ 124 $ 3,105 2022: Net income $ 2,027 $ 111 $ 2,138 Other comprehensive income (loss): Foreign currency translation adjustments 11 — 11 Financial instruments 221 (55) 166 Pension and other postretirement benefits 3 (6) (3) Total other comprehensive income 235 (61) 174 Comprehensive income $ 2,262 $ 50 $ 2,312 See Notes to Condensed Financial Information of Parent. SEMPRA CONDENSED BALANCE SHEETS (Dollars in millions) December 31, 2024 2023 Assets: Cash and cash equivalents $ 1,416 $ 3 Restricted cash 2 2 Due from affiliates 88 105 Income taxes receivable, net 71 — Other current assets 10 11 Total current assets 1,587 121 Investments in subsidiaries 42,305 38,499 Due from affiliates 25 18 Deferred income taxes 209 429 Other long-term assets 1,152 1,095 Total assets $ 45,278 $ 40,162 Liabilities and shareholders’ equity: Short-term debt $ — $ 365 Due to affiliates 241 235 Other current liabilities 1,410 819 Total current liabilities 1,651 1,419 Long-term debt 11,028 8,461 Due to affiliates 739 988 Other long-term liabilities 638 619 Commitments and contingencies (Note 4) Shareholders’ equity 31,222 28,675 Total liabilities and shareholders’ equity $ 45,278 $ 40,162 See Notes to Condensed Financial Information of Parent. SEMPRA CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2024 2023 2022 Net cash provided by operating activities $ 120 $ 1,576 $ 775 Expenditures for property, plant and equipment (3) (5) (7) Proceeds from sale of assets — 2 — Capital contributions to investees (933) (1,749) (661) Distributions from investments 9 108 — Purchases of trust assets (63) (78) (114) Proceeds from sales of trust assets 68 69 123 Increase in loans to affiliates, net (117) (90) (92) Premiums on corporate-owned life insurance policies (1) (1) (3) Net cash used in investing activities (1,040) (1,744) (754) Common dividends paid (1,499) (1,483) (1,430) Preferred dividends paid (44) (44) (44) Issuances of common stock, net 1,219 145 4 Repurchases of common stock (43) (32) (478) Issuances of debt (maturities greater than 90 days) 3,695 1,918 1,569 Payments on debt (maturities greater than 90 days) (350) (672) (322) Decrease in short-term debt, net (365) (89) (785) (Decrease) increase in loans from affiliates, net (241) 220 (226) Proceeds from sales of noncontrolling interests, net — — 1,732 Other (38) (10) (8) Net cash provided by (used in) financing activities 2,334 (47) 12 Effect of exchange rate changes on cash, cash equivalents and restricted cash (1) — (1) Increase (decrease) in cash, cash equivalents and restricted cash 1,413 (215) 32 Cash, cash equivalents and restricted cash, January 1 5 220 188 Cash, cash equivalents and restricted cash, December 31 $ 1,418 $ 5 $ 220 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Accrued interest receivable capitalized to note receivable $ 17 $ 16 $ 18 Preferred dividends declared but not paid 11 11 11 Common dividends declared but not paid 393 376 360 Common dividends issued in stock 54 — — Net exercise of stock options 9 — — Equitization of amounts due from affiliates 110 92 93 See Notes to Condensed Financial Information of Parent. The condensed financial information of Sempra has been prepared in accordance with SEC Regulation S-X Rule 5-04 and Rule 12-04. We apply the same accounting policies as in the consolidated financial statements of Sempra, except that Sempra accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information. This financial information should be read in conjunction with Sempra’s consolidated financial statements and the accompanying notes thereto included in this Form 10-K. Sempra received cash dividends from its subsidiaries totaling $908 million, $1.9 billion and $832 million in 2024, 2023 and 2022, respectively. We describe in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had or may have a significant effect on Sempra’s results of operations, financial condition, cash flows or disclosures. SHORT-TERM DEBT Committed Line of Credit At December 31, 2024, Sempra had capacity of $4.0 billion under a committed line of credit, which provides liquidity and supports its commercial paper program, with available unused credit of $4.0 billion before reductions of any unamortized discounts. The principal terms of Sempra’s committed line of credit include the following: ▪ The facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in the facility. ▪ The facility provides for the issuance of $200 million of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra has the right to increase its letter of credit commitment to up to $500 million. No letters of credit were outstanding at December 31, 2024. ▪ Borrowings bear interest at a benchmark rate plus a margin that varies with Sempra’s credit rating. ▪ Sempra must maintain a ratio of indebtedness to total capitalization (as defined in its credit facility) of no more than 65% at the end of each quarter. At December 31, 2024, Sempra was in compliance with this ratio under its credit facility. LONG-TERM DEBT The following table shows the detail and maturities of uncollateralized long-term debt outstanding. LONG-TERM DEBT (Dollars in millions) December 31, 2024 2023 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Current portion of long-term debt (750) — Unamortized discount on long-term debt (30) (29) Unamortized debt issuance costs (100) (68) Total long-term debt $ 11,028 $ 8,461 (1) Callable long-term debt not subject to make-whole provisions. Sempra issued the following fixed-to-fixed reset rate junior subordinated notes in 2024: ▪ In March 2024, Sempra issued $600 million aggregate principal amount of 6.875% junior subordinated notes maturing on October 1, 2054, and received proceeds of $593 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). In May 2024, Sempra issued an additional $500 million aggregate principal amount of these junior subordinated notes and 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. Interest accrues from and including March 14, 2024 to, but excluding, October 1, 2029 at the rate of 6.875% per annum. ▪ In September 2024, Sempra issued $1.25 billion aggregate principal amount of 6.40% junior subordinated notes maturing on October 1, 2054, and received proceeds of $1.235 billion (net of underwriting discounts and debt issuance costs of $15 million). Interest accrues from and including September 9, 2024 to, but excluding, October 1, 2034 at the rate of 6.40% per annum. ▪ In November 2024, Sempra issued $400 million aggregate principal amount of 6.625% junior subordinated notes maturing on April 1, 2055, and received proceeds of $395 million (net of underwriting discounts and debt issuance costs of $5 million). Interest accrues from and including November 21, 2024 to, but excluding, April 1, 2030 at the rate of 6.625% per annum. ▪ In November 2024, Sempra issued $600 million aggregate principal amount of 6.55% junior subordinated notes maturing on April 1, 2055, and received proceeds of $593 million (net of underwriting discounts and debt issuance costs of $7 million). Interest accrues from and including November 21, 2024 to, but excluding, April 1, 2035 at the rate of 6.55% per annum. The interest rates on the notes will be reset on: ▪ October 1, 2029 (for the March 2024 and May 2024 issuances), ▪ October 1, 2034 (for the September 2024 issuance), ▪ April 1, 2030 (for the $400 million November 2024 issuance), and ▪ April 1, 2035 (for the $600 million November 2024 issuance), and on each subsequent five-year period beginning on October 1 or April 1, as applicable, of every fifth year thereafter, 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 ▪ 2.789% (for the March 2024 and May 2024 issuances), ▪ 2.632% (for the September 2024 issuance), ▪ 2.354% (for the $400 million November 2024 issuance), and ▪ 2.138% (for the $600 million November 2024 issuance). Interest is payable on the notes 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) or April 1, 2025 (for the September 2024 and November 2024 issuances). 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), October 1, 2034 (for the September 2024 issuance), April 1, 2030 (for the $400 million November 2024 issuance), and April 1, 2035 (for the $600 million November 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. We used, or plan to use, the proceeds from the offerings for general corporate purposes, including repayment of commercial paper and other indebtedness. At December 31, 2024, scheduled maturities of Sempra’s long-term debt are $750 million in 2025, $550 million in 2026, $750 million in 2027, $1.0 billion in 2028, $500 million in 2029 and $8.4 billion thereafter. Additional information on Sempra’s short-term and long-term debt is provided in Note 6 of the Notes to Consolidated Financial Statements. At December 31, 2024, Sempra has an operating lease liability related to its corporate headquarters building of approximately $147 million. Sempra expects undiscounted lease payments for its operating lease to be $12 million in each of 2025 through 2028, $13 million in 2029 and $151 million thereafter through 2040 for a total of $212 million. The operating lease cost was $14 million at December 31, 2024, 2023 and 2022. The weighted-average discount rate of the lease is 4.7% at December 31, 2024 and 2023. For other contingencies and guarantees related to Sempra, refer to Notes 5 and 15 of the Notes to Consolidated Financial Statements.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net of tax amount, attributable to parent	$ 2,862	$ 3,075	$ 2,139

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Insider Trading Policies and Pr

Insider Trading Policies and Procedures	12 Months Ended
	Dec. 31, 2024
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Cybersecurity Risk Management a

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	CYBERSECURITY RISK MANAGEMENT Sempra, SDG&E and SoCalGas have cybersecurity risk management processes in place that are intended to protect the confidentiality, integrity, and availability of our critical infrastructure, systems and information. These cybersecurity risk management processes include cybersecurity incident response plans that are integrated into each entity’s respective enterprise risk management and emergency management programs. Our cybersecurity processes are largely designed and assessed based on the National Institute of Standards and Technology Cybersecurity Framework and the DOE’s Cybersecurity Capability Maturity Model standards. This does not imply that we meet any technical standards, specifications, or requirements, only that we use these standards as a guide to help us identify, assess, and manage cybersecurity risks relevant to our business. Our cybersecurity risk management processes include: ▪ risk assessments performed by internal personnel and third-party advisors designed to help identify material cybersecurity risks to our critical systems, information, services, and our broader enterprise information technology environments ▪ information security teams principally responsible for developing and implementing (1) cybersecurity risk assessment processes, (2) information security controls, and (3) response plans to cybersecurity incidents ▪ the use of external service providers, where appropriate, to assess, test or otherwise assist with aspects of our information security controls ▪ cybersecurity awareness training and policies designed to address social engineering attacks targeting employees and contractors ▪ cybersecurity incident response plans that include procedures for responding to and reporting, if applicable, certain cybersecurity incidents ▪ risk management processes for third-party service providers, suppliers, and vendors We have not identified risks from known cybersecurity threats, including as a result of any prior cybersecurity incidents, that have materially affected or are reasonably likely to materially affect our results of operations, financial condition, cash flows and/or prospects.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	Sempra, SDG&E and SoCalGas have cybersecurity risk management processes in place that are intended to protect the confidentiality, integrity, and availability of our critical infrastructure, systems and information. These cybersecurity risk management processes include cybersecurity incident response plans that are integrated into each entity’s respective enterprise risk management and emergency management programs.
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	Sempra’s, SDG&E’s and SoCalGas’ respective boards of directors consider cybersecurity risk as part of their risk oversight function. The Sempra board of directors has delegated to its SST Committee, which is entirely composed of independent directors under the independence standards established by the NYSE, oversight of cybersecurity and other information and operational technology risks. The SST Committee reports to the Sempra board of directors regarding the Committee’s activities, including those related to cybersecurity. The SST Committee receives briefings on cybersecurity topics from Sempra’s chief information security officer, internal information security staff or external experts in part for continuing education on topics that impact public companies. The SST Committee as well as the SDG&E and SoCalGas boards of directors oversee management’s implementation of our cybersecurity risk management processes and receive regular reports from management on our material cybersecurity risks. In addition, management updates the SST Committee and SDG&E and SoCalGas boards of directors about certain cybersecurity incidents. The SDG&E and SoCalGas boards of directors receive briefings from SDG&E’s and SoCalGas’ chief information officer and internal information security staff. SDG&E’s and SoCalGas’ boards of directors also have safety committees that, at times, may oversee the matters described above on behalf of those companies’ respective boards of directors.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Sempra board of directors has delegated to its SST Committee, which is entirely composed of independent directors under the independence standards established by the NYSE, oversight of cybersecurity and other information and operational technology risks. The SST Committee reports to the Sempra board of directors regarding the Committee’s activities, including those related to cybersecurity. The SST Committee receives briefings on cybersecurity topics from Sempra’s chief information security officer, internal information security staff or external experts in part for continuing education on topics that impact public companies. The SST Committee as well as the SDG&E and SoCalGas boards of directors oversee management’s implementation of our cybersecurity risk management processes and receive regular reports from management on our material cybersecurity risks. In addition, management updates the SST Committee and SDG&E and SoCalGas boards of directors about certain cybersecurity incidents. The SDG&E and SoCalGas boards of directors receive briefings from SDG&E’s and SoCalGas’ chief information officer and internal information security staff. SDG&E’s and SoCalGas’ boards of directors also have safety committees that, at times, may oversee the matters described above on behalf of those companies’ respective boards of directors.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	Sempra’s, SDG&E’s and SoCalGas’ respective boards of directors consider cybersecurity risk as part of their risk oversight function. The Sempra board of directors has delegated to its SST Committee, which is entirely composed of independent directors under the independence standards established by the NYSE, oversight of cybersecurity and other information and operational technology risks. The SST Committee reports to the Sempra board of directors regarding the Committee’s activities, including those related to cybersecurity. The SST Committee receives briefings on cybersecurity topics from Sempra’s chief information security officer, internal information security staff or external experts in part for continuing education on topics that impact public companies. The SST Committee as well as the SDG&E and SoCalGas boards of directors oversee management’s implementation of our cybersecurity risk management processes and receive regular reports from management on our material cybersecurity risks. In addition, management updates the SST Committee and SDG&E and SoCalGas boards of directors about certain cybersecurity incidents. The SDG&E and SoCalGas boards of directors receive briefings from SDG&E’s and SoCalGas’ chief information officer and internal information security staff. SDG&E’s and SoCalGas’ boards of directors also have safety committees that, at times, may oversee the matters described above on behalf of those companies’ respective boards of directors.
Cybersecurity Risk Role of Management [Text Block]	Sempra’s, SDG&E’s and SoCalGas’ respective boards of directors consider cybersecurity risk as part of their risk oversight function. The Sempra board of directors has delegated to its SST Committee, which is entirely composed of independent directors under the independence standards established by the NYSE, oversight of cybersecurity and other information and operational technology risks. The SST Committee reports to the Sempra board of directors regarding the Committee’s activities, including those related to cybersecurity. The SST Committee receives briefings on cybersecurity topics from Sempra’s chief information security officer, internal information security staff or external experts in part for continuing education on topics that impact public companies. The SST Committee as well as the SDG&E and SoCalGas boards of directors oversee management’s implementation of our cybersecurity risk management processes and receive regular reports from management on our material cybersecurity risks. In addition, management updates the SST Committee and SDG&E and SoCalGas boards of directors about certain cybersecurity incidents. The SDG&E and SoCalGas boards of directors receive briefings from SDG&E’s and SoCalGas’ chief information officer and internal information security staff. SDG&E’s and SoCalGas’ boards of directors also have safety committees that, at times, may oversee the matters described above on behalf of those companies’ respective boards of directors. We have formed cybersecurity councils to provide overall corporate oversight for managing material risks from cybersecurity threats. The cybersecurity councils meet regularly to receive updates on cybersecurity developments at Sempra and our consolidated entities from their cybersecurity management teams. Our cybersecurity management teams supervise efforts designed to prevent, detect, mitigate, and remediate cybersecurity risks and incidents through various means, which may include briefings from internal information security personnel; threat intelligence and other information obtained from governmental, public or private sources, including external consultants engaged by us; and alerts and reports produced by information security tools deployed in the information technology environment. Cybersecurity management also supervises both our internal cybersecurity personnel and our retained external cybersecurity consultants. Sempra’s director of cybersecurity governance & chief information security officer provides additional oversight and support for the operational cybersecurity activities at our consolidated entities.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	We have formed cybersecurity councils to provide overall corporate oversight for managing material risks from cybersecurity threats. The cybersecurity councils meet regularly to receive updates on cybersecurity developments at Sempra and our consolidated entities from their cybersecurity management teams. Our cybersecurity management teams supervise efforts designed to prevent, detect, mitigate, and remediate cybersecurity risks and incidents through various means, which may include briefings from internal information security personnel; threat intelligence and other information obtained from governmental, public or private sources, including external consultants engaged by us; and alerts and reports produced by information security tools deployed in the information technology environment. Cybersecurity management also supervises both our internal cybersecurity personnel and our retained external cybersecurity consultants. Sempra’s director of cybersecurity governance & chief information security officer provides additional oversight and support for the operational cybersecurity activities at our consolidated entities. Our cybersecurity materiality assessment teams, which include chief information security officers, chief information officers, chief risk officers, chief accounting officers or chief financial officers, and general counsels, help assess the materiality of certain cybersecurity incidents. The cybersecurity councils, cybersecurity management teams and materiality assessment teams include members with decades of operational experience as cybersecurity professionals as well as management with decades of service in the areas of information and operational technology and legal, compliance, financial reporting and enterprise risk management. Some of these members hold relevant degrees and certifications that we believe enhance our ability to manage and respond to cybersecurity risks, including, among others, bachelor’s and/or master’s degrees in cybersecurity and computer science as well as certified information systems security professional, certified incident handler, and certified information security manager certifications.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	The cybersecurity councils, cybersecurity management teams and materiality assessment teams include members with decades of operational experience as cybersecurity professionals as well as management with decades of service in the areas of information and operational technology and legal, compliance, financial reporting and enterprise risk management. Some of these members hold relevant degrees and certifications that we believe enhance our ability to manage and respond to cybersecurity risks, including, among others, bachelor’s and/or master’s degrees in cybersecurity and computer science as well as certified information systems security professional, certified incident handler, and certified information security manager certifications
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	We have formed cybersecurity councils to provide overall corporate oversight for managing material risks from cybersecurity threats. The cybersecurity councils meet regularly to receive updates on cybersecurity developments at Sempra and our consolidated entities from their cybersecurity management teams. Our cybersecurity management teams supervise efforts designed to prevent, detect, mitigate, and remediate cybersecurity risks and incidents through various means, which may include briefings from internal information security personnel; threat intelligence and other information obtained from governmental, public or private sources, including external consultants engaged by us; and alerts and reports produced by information security tools deployed in the information technology environment. Cybersecurity management also supervises both our internal cybersecurity personnel and our retained external cybersecurity consultants. Sempra’s director of cybersecurity governance & chief information security officer provides additional oversight and support for the operational cybersecurity activities at our consolidated entities.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

SIGNIFICANT ACCOUNTING POLICI_2

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Consolidated Financial Statements include the accounts of Sempra, 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 operating and reportable segments, which we describe in Note 16. 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 operating and 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 operating and 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 Sempra’s consolidated financial statements.
Use of Estimates in the Preparation of the Financial Statements	Use of Estimates in the Preparation of the Financial Statements We have prepared our financial statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates.
Subsequent Events	Subsequent Events We evaluated events and transactions that occurred after December 31, 2024 through the date the financial statements were issued, and in the opinion of management, the accompanying financial statements reflect all adjustments and disclosures necessary for a fair presentation.
Regulated Operations	REGULATED OPERATIONS SDG&E’s and SoCalGas’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from customers, the excess would be refunded to customers, generally by reducing future rates. Regulatory assets and liabilities may also arise from other transactions such as unrealized losses and/or gains on fixed-price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, the FERC, requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and, in the case of Oncor, certain cities and are subject to regulatory rate-setting processes and earnings oversight. Oncor and Sharyland Utilities prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. Sempra Infrastructure’s natural gas distribution utility, Ecogas, also applies U.S. GAAP provisions governing rate-regulated operations, including the same evaluation of probability of recovery of regulatory assets described above. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP.
Fair Value Measurements	FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily NDT and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, short-term investments, and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and, until December 31, 2022, fixed-price electricity positions, at SDG&E and the Support Agreement at Sempra Infrastructure. The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following: ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate instruments and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and, until December 31, 2022, fixed-price electricity positions, at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” We further discuss derivative assets and liabilities in Note 9. ▪ 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.” Fair Value of Financial Instruments
Variable Interest Entities	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess: ▪ the purpose and design of the VIE; ▪ the nature of the VIE’s risks and the risks we absorb; ▪ the power to direct activities that most significantly impact the economic performance of the VIE; and ▪ the obligation to absorb losses or the right to receive benefits that could be significant to the VIE. 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.
Cash and Cash Equivalents and Restricted Cash	CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase. Restricted cash includes: ▪ certain funds at Port Arthur LNG for which withdrawals and usage are dictated by its debt agreements ▪ funds held as collateral in lieu of a customer’s letters of credit associated with its LNG storage and regasification agreement ▪ funds denominated in U.S. dollars and Mexican pesos to pay for rights-of-way and other costs pursuant to trust agreements related to pipeline projects ▪ funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares
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.
Concentration of Credit Risk	CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by the respective credit departments at each of the Registrants and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a regular basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: ▪ prospective counterparties’ financial condition (including credit ratings) ▪ collateral requirements ▪ the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty ▪ downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance in our allowances for credit losses.
Inventories	INVENTORIES SDG&E and SoCalGas value natural gas inventory using the last-in first-out method. Sempra Infrastructure values natural gas inventory at the lower of average cost or net realizable value. We record natural gas to inventory when injected and then to expense when the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Sempra Infrastructure values LNG inventory at the lower of average cost or net realizable value. We record LNG to inventory when delivered to our terminals and then to expense when transported from our terminals.
Greenhouse Gas Allowances and Obligations and Emissions and Renewable Energy Certificates	GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS SDG&E, SoCalGas and Sempra Infrastructure are required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas consumption. SDG&E and SoCalGas receive allocations of GHG allowances on behalf of their customers at no cost and purchase any additional allowances required. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Infrastructure records the cost of GHG obligations in cost of sales. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. RENEWABLE ENERGY CERTIFICATES RECs are energy rights established by governmental agencies for the environmental and social promotion of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable energy PPAs, internal generation or separate purchases in the market to comply with the RPS Program established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with the RPS Program. The cost of RECs at SDG&E, which is recoverable in rates, is recorded in Cost of Electric Fuel and Purchased Power on the Statements of Operations.
Long-lived Assets	LONG-LIVED ASSETS We test long-lived assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets. Long-lived assets include intangible assets subject to amortization, but do not include investments in unconsolidated entities. A long-lived asset may be impaired when the estimated future undiscounted cash flows are less than the carrying amount of the asset. If that comparison indicates that the asset’s carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the asset. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
Goodwill and Other Intangible Assets	GOODWILL AND OTHER INTANGIBLE ASSETS Goodwill Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies measured at the time of acquisition. Goodwill is not amortized, but we test it for impairment annually on October 1 or whenever events or changes in circumstances necessitate an evaluation. If the carrying value of the reporting unit, including goodwill, exceeds its fair value, we record a goodwill impairment loss as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For our annual goodwill impairment testing, we have the option to first make a qualitative assessment of whether it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount before applying the quantitative goodwill impairment test. If we elect to perform the qualitative assessment, we evaluate relevant events and circumstances, including but not limited to, macroeconomic conditions, industry and market considerations, cost factors and the overall financial performance of the reporting unit. If, after assessing these qualitative factors, we determine that it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, then we perform the quantitative goodwill impairment test. If, after performing the quantitative goodwill impairment test, we determine that goodwill is impaired, we record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. Other Intangible Assets at December 31, 2024 primarily include: ▪ renewable energy transmission and consumption permits granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar; ▪ a favorable O&M agreement acquired in connection with the acquisition of Ductos y Energéticos del Norte, S. de R.L. de C.V.; and ▪ the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ.
Property, Plant and Equipment (PP&E)	PROPERTY, PLANT AND EQUIPMENT
Capitalized Finance Costs	SDG&E and SoCalGas finance construction projects with debt and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of PP&E. SDG&E and SoCalGas earn a return on the capitalized AFUDC after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives of the assets. Pipeline projects under construction by Sempra Infrastructure that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC.
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record AROs for the present value of liabilities of future costs expected to be incurred when assets are retired from service if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated but performance is conditional upon a future event. We record the estimated retirement cost using the present value of the obligation at the time the asset is placed into service and recognize that cost over the life of the related asset by depreciating the asset retirement cost and accreting the obligation until the liability is settled. Our rate-regulated entities record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with U.S. GAAP and costs recovered through the rate-making process.
Contingencies	CONTINGENCIES We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and if: ▪ information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and ▪ the amount of the loss or a range of possible losses can be reasonably estimated. We do not accrue contingencies that might result in gains. We assess contingencies for litigation claims, environmental remediation and other events.
Comprehensive Income	COMPREHENSIVE INCOME Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including: ▪ foreign currency translation adjustments ▪ certain hedging activities ▪ changes in unamortized net actuarial gain or loss and prior service cost related to pension and PBOP plans
Operation and Maintenance Expenses	OPERATION AND MAINTENANCE EXPENSES Operation and Maintenance includes O&M and general and administrative costs, consisting primarily of personnel costs, purchased materials and services, insurance, rent, provisions for expected credit losses and litigation expense (except for litigation expense included in Aliso Canyon Litigation and Regulatory Matters).
Legal Fees	LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred and amounts are estimable. LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.
Foreign Currency Translation and Transactions	FOREIGN CURRENCY TRANSLATION AND TRANSACTIONS Our natural gas distribution utility in Mexico, Ecogas, uses its local currency as its functional currency. The assets and liabilities of its foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings but are reflected in OCI and AOCI. Cash flows of this consolidated foreign subsidiary are translated into U.S. dollars using average exchange rates for the period. We report the effect of exchange rate changes on cash balances held in foreign currencies in Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash on Sempra’s Consolidated Statements of Cash Flows. Foreign currency transaction gains (losses), net, are included in Other Income, Net, on Sempra’s Consolidated Statements of Operations.
Income Taxes	INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. ITCs from prior years are generally amortized to income by SDG&E and SoCalGas over the estimated service lives of the properties as required by the CPUC. However, 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 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. Under the regulatory accounting treatment required for flow-through temporary differences, the Registrants recognize: ▪ regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪ regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, the position we take must have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities in order to qualify for recognition. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR. We accrue income tax to the extent we intend to repatriate cash to the U.S. from our continuing international operations. We currently do not record deferred income taxes for other basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries because they are indefinitely reinvested. We recognize income tax expense for basis differences related to global intangible low-taxed income as a period cost if and when incurred. We recognize interest and penalties related to income taxes in income tax expense. We provide additional information about income taxes in Note 7.
Revenue from Contract with Customer	Revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity or service is provided to customers and invoices are issued for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of respective performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ ability to collect from customers, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: ▪ The transmission, distribution and storage of natural gas at: ◦ SDG&E ◦ SoCalGas ◦ Sempra’s Ecogas ▪ The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue from customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings and collections, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. SDG&E and SoCalGas recognize revenues from the sale of allocated California GHG emission allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and SDG&E and SoCalGas have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Revenues at Sempra Infrastructure typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency impacts and the actual quantity of commodity transported. Sempra Infrastructure develops, invests in and operates solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated and delivered. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities as the power is delivered at the interconnection point. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 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 December 31, 2024. Contract Liabilities from Revenues from Contracts with Customers REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled Revenues. As we discuss above, the regulatory framework requires SDG&E and SoCalGas to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive Mechanisms. SoCalGas is subject to the GCIM and is eligible for financial awards or subject to financial penalties depending on its performance in relation to specific benchmarks. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize SDG&E and SoCalGas to collect, or in the case of CPUC programmatic activities, to apply for additional, revenue requirements beyond base rates from customers for certain operating and capital related costs (depreciation, taxes and return on rate base), including for: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, environmental compliance, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity or service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded in a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met when the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund of amounts accumulated for authorized programs, including limitations on the program’s total cost, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in delays or disallowances of recovery from customers. We discuss balancing accounts and their effects further in Note 4. Other Revenues Sempra Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and refined products terminals. We discuss the recognition of lease income in Note 15. Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes. Sempra Infrastructure also recognizes other revenues associated with derivatives related to the sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of these derivatives.
Investments in Noncontrolling Interests	We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Consolidated Statements of Operations. Distributions received from equity method investees are classified in the 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. Our equity method investments include various domestic and foreign entities. Our domestic equity method investees are typically partnerships that are pass-through entities for income tax purposes and therefore they do not record income tax. Sempra’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense on the Consolidated Statements of Operations. Our foreign equity method investees are generally corporations whose operations are taxable on a standalone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax. See Note 7 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.
Employee Benefit Plans	Plan Assets Investment Strategy for Sempra’s Pension Master Trust Sempra’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. We maintain additional trusts, as we discuss below, for certain of SDG&E’s and SoCalGas’ PBOP plans. Other than through indexing and certain collective investment strategies, the trusts do not invest in securities of Sempra. We maintain asset allocations at strategic levels within reasonable bands of variance. The asset allocations are reviewed by our Plan Funding Committee and our Pension and Benefits Investment Committee (the Committees) on a regular basis to help ensure that plan assets are positioned to meet plan obligations. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪ long-term cost ▪ variability and level of contributions ▪ funded status ▪ a range of expected outcomes over varying confidence levels In accordance with the Sempra pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on plan assets in our pension and PBOP plans is based on the weighted average of the plans’ target investment allocations to specific asset classes as of the measurement date. We expect a return of between 4% and 12% on return-seeking assets and between 2% and 6% for risk-mitigating assets. Certain trusts that hold assets for SDG&E’s and SoCalGas’ PBOP plans are subject to taxation, which impacts the expected after-tax return on plan assets. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. Investment Strategy for Sempra’s, SDG&E’s and SoCalGas’ PBOP Plans
Share-based Compensation	Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three SEMPRA NONQUALIFIED STOCK OPTIONS SEMPRA RESTRICTED STOCK UNITS We use Sempra’s common stock price at the grant date to estimate the fair value of our service-based RSUs and our RSUs that vest based on the compound annual growth rate of Sempra’s EPS.
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 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 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 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 net income 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. On December 31, 2024, Port Arthur LNG voluntarily de-designated the remaining interest rate swaps, which are currently hedging interest payments until March 2026. At the time of de-designation, $37 million of deferred gains related to the de-designated notional amount were included in AOCI, which will remain in AOCI until either the hedged interest payments impact net income or such hedged interest payments become probable of not occurring. 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.
Noncontrolling interests	NONCONTROLLING INTERESTS Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI.
Earnings Per 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 Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Leases	As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, aircraft, power generating facilities and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for refined products terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately. Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record a corresponding ROU asset, initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. We test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets. For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. SDG&E and SoCalGas recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. SDG&E and SoCalGas recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. Our leases do not contain any material residual value guarantees, restrictions or covenants.
Lessor, Leases	Generally, we recognize operating lease income on a straight-line basis over the lease term, and sales-type lease income based on the effective interest method over the lease term. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary in amount from one period to the next. In addition to minimum fixed payments, our refined products terminals receive variable lease payments for barrels delivered that exceed minimum delivery requirements.
Environmental Costs	We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: At SDG&E and SoCalGas, costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates. The environmental issues currently facing us, except for those resolved during the last three years, include (1) investigation and remediation of SDG&E’s and SoCalGas’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by SDG&E and SoCalGas at which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS.
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. We adopted the standard on December 31, 2024 and revised our segment reporting disclosures in Note 16 on a retrospective basis. 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 annual reporting periods beginning after December 15, 2026, and interim periods within annual reporting periods 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.

SIGNIFICANT ACCOUNTING POLICI_3

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) December 31, 2024 2023 Sempra: Cash and cash equivalents $ 1,565 $ 236 Restricted cash, current 21 49 Restricted cash, noncurrent 3 104 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 1,589 $ 389
Schedule of 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 2022 Sempra: Allowances for credit losses at January 1 $ 533 $ 181 $ 136 Provisions for expected credit losses 203 468 123 Write-offs (222) (116) (78) Allowances for credit losses at December 31 $ 514 $ 533 $ 181 SDG&E: Allowances for credit losses at January 1 $ 144 $ 78 $ 66 Provisions for expected credit losses 52 115 54 Write-offs (82) (49) (42) Allowances for credit losses at December 31 $ 114 $ 144 $ 78 SoCalGas: Allowances for credit losses at January 1 $ 331 $ 98 $ 69 Provisions for expected credit losses 94 300 65 Write-offs (140) (67) (36) Allowances for credit losses at December 31 $ 285 $ 331 $ 98 Allowances for credit losses related to trade receivables and other receivables are included in the Consolidated Balance Sheets as follows: ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) December 31, 2024 2023 Sempra: Accounts receivable – trade, net $ 447 $ 480 Accounts receivable – other, net 53 52 Other long-term assets 14 1 Total allowances for credit losses $ 514 $ 533 SDG&E: Accounts receivable – trade, net $ 81 $ 116 Accounts receivable – other, net 25 27 Other long-term assets 8 1 Total allowances for credit losses $ 114 $ 144 SoCalGas: Accounts receivable – trade, net $ 251 $ 306 Accounts receivable – other, net 28 25 Other long-term assets 6 — Total allowances for credit losses $ 285 $ 331
Schedule of Related Party Transactions	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) December 31, 2024 2023 Sempra: Tax sharing agreement with Oncor Holdings $ 8 $ 25 Various affiliates 5 6 Total due from unconsolidated affiliates – current $ 13 $ 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 (19) (17) 5.5% Note due January 19, 2028 (48) — 5.5% Note due July 18, 2028 (41) — TAG Norte – 5.74% Note due December 17, 2029 (1) (209) (198) Total due to unconsolidated affiliates – noncurrent $ (352) $ (307) SDG&E: Sempra $ (42) $ (44) SoCalGas (14) (21) Various affiliates (3) (8) Total due to unconsolidated affiliates – current $ (59) $ (73) Income taxes due from Sempra (2) $ 38 $ 246 SoCalGas: SDG&E $ 14 $ 21 Various affiliates 2 1 Total due from unconsolidated affiliates – current $ 16 $ 22 Sempra $ (38) $ (38) Total due to unconsolidated affiliates – current $ (38) $ (38) Income taxes due (to) from Sempra (2) $ (6) $ 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. The following table summarizes income statement information from unconsolidated affiliates. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Revenues $ 40 $ 44 $ 41 Interest income — — 16 Interest expense 16 15 15 SDG&E: Revenues $ 23 $ 21 $ 16 Cost of sales 146 113 92 SoCalGas: Revenues $ 169 $ 124 $ 100 Cost of sales (1) (5) 35 (9) (1)
Schedule of Inventory	The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Natural gas $ 163 $ 174 $ 1 $ 1 $ 148 $ 155 LNG 27 9 — — — — Materials and supplies 369 299 201 152 139 122 Total $ 559 $ 482 $ 202 $ 153 $ 287 $ 277
Schedule of Regulated Operations	The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets. WILDFIRE FUND (Dollars in millions) December 31, Location 2024 2023 Wildfire Fund asset: Current Prepaid Expenses $ 14 $ 28 Noncurrent Wildfire Fund 262 269 Wildfire Fund obligation: Current Other Current Liabilities 13 13 Noncurrent Deferred Credits and Other 31 42 The following table summarizes the cost of capital for SDG&E and SoCalGas. The authorized weighting remained unchanged for each of the years presented. AUTHORIZED COST OF CAPITAL Authorized weighting 2022 2023 2024 2025 2022 2023 (1) 2024 2025 Return on rate base Weighted return on rate base SDG&E: Long-Term Debt 45.25 % 4.59 % 4.05 % 4.34 % 4.34 % 2.08 % 1.83 % 1.96 % 1.96 % Preferred Equity 2.75 6.22 6.22 6.22 6.22 0.17 0.17 0.17 0.17 Common Equity 52.00 10.20 9.95 10.65 10.23 5.30 5.17 5.54 5.32 100.00 % 7.55 % 7.18 % 7.67 % 7.45 % SoCalGas: Long-Term Debt 45.60 % 4.23 % 4.07 % 4.54 % 4.63 % 1.93 % 1.86 % 2.07 % 2.11 % Preferred Equity 2.40 6.00 6.00 6.00 6.00 0.14 0.14 0.14 0.14 Common Equity 52.00 10.05 9.80 10.50 10.08 5.23 5.10 5.46 5.24 100.00 % 7.30 % 7.10 % 7.67 % 7.49 % (1) Total weighted return on rate base for SDG&E does not sum due to rounding differences.
Schedule of Other Intangible Assets	Other Intangible Assets included on Sempra’s Consolidated Balance Sheets are as follows: OTHER INTANGIBLE ASSETS (Dollars in millions) Amortization period December 31, 2024 2023 Sempra: Renewable energy transmission and consumption permits 15 to 19 $ 169 $ 169 O&M agreement 23 66 66 ESJ PPA 14 190 190 Other 10 to indefinite 15 15 440 440 Less accumulated amortization: Renewable energy transmission and consumption permits (68) (59) O&M agreement (20) (17) ESJ PPA (51) (37) Other (9) (9) (148) (122) $ 292 $ 318
Schedule of Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) December 31, Depreciation rates for years ended 2024 2023 2024 2023 2022 SDG&E: Natural gas operations $ 4,531 $ 4,175 2.62 % 2.60 % 2.57 % Electric distribution 12,542 11,597 4.21 4.05 3.94 Electric transmission (1) 8,878 8,504 3.06 3.04 3.03 Electric generation 2,527 2,515 5.43 5.18 5.11 Other electric 2,722 2,507 6.95 7.05 7.03 Construction work in progress (1) 1,962 1,620 N/A N/A N/A Total SDG&E 33,162 30,918 SoCalGas: Natural gas operations 27,191 25,506 3.68 3.64 3.57 Other non-utility 32 50 0.98 1.03 1.54 Construction work in progress 1,861 1,469 N/A N/A N/A Total SoCalGas 29,084 27,025 Other Sempra (2) : Estimated useful lives Weighted-average useful life Land and land rights 498 488 16 to 44 years (3) 37 Machinery and equipment: Pipelines and storage 4,355 3,883 41 to 49 years 42 Generating plants 1,820 1,815 11 to 28 years 26 LNG terminal 1,156 1,139 42 years 42 Refined products terminals 876 656 37 years 37 Other 348 346 1 to 21 years 15 Construction work in progress 8,781 5,930 N/A N/A Other 317 295 1 to 35 years 16 18,151 14,552 Total Sempra $ 80,397 $ 72,495 (1) At December 31, 2024, includes $563 in electric transmission assets and $1 in construction work in progress related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. SDG&E’s share of operating expenses is included in SDG&E’s and Sempra’s Consolidated Statements of Operations. (2) Includes $290 and $310 at December 31, 2024 and 2023, respectively, of utility plant, primarily pipelines and other distribution assets at Ecogas. (3) Estimated useful lives are for land rights. DEPRECIATION EXPENSE (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra $ 2,409 $ 2,202 $ 1,995 SDG&E 1,216 1,092 977 SoCalGas 903 833 755 ACCUMULATED DEPRECIATION AND AMORTIZATION (Dollars in millions) December 31, 2024 2023 SDG&E: Accumulated depreciation: Natural gas operations $ 1,121 $ 1,048 Electric transmission, distribution and generation (1) 6,930 6,321 Total SDG&E 8,051 7,369 SoCalGas: Accumulated depreciation: Natural gas operations 8,315 7,835 Other non-utility 15 17 Total SoCalGas 8,330 7,852 Other Sempra: Accumulated depreciation – other (2) 2,579 2,314 Total Sempra $ 18,960 $ 17,535 (1) Includes $338 at December 31, 2024 related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities. (2)
Schedule of Capitalized Financing Costs	The table below summarizes capitalized financing costs, comprised of capitalized interest and AFUDC related to debt. CAPITALIZED FINANCING COSTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra $ 629 $ 448 $ 255 SDG&E 100 116 116 SoCalGas 101 77 73
Schedule of Asset Retirement Obligations	The changes in AROs are as follows: CHANGES IN ASSET RETIREMENT OBLIGATIONS (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2022 2024 2023 2022 2024 2023 2022 Balance at January 1 (1) $ 3,831 $ 3,712 $ 3,538 $ 894 $ 887 $ 890 $ 2,847 $ 2,743 $ 2,582 Accretion expense 156 148 141 37 37 37 114 106 101 Liabilities incurred — 18 21 — 15 6 — — — Payments (65) (62) (57) (57) (59) (54) (8) (3) (3) Revisions 3 15 69 26 14 8 (23) 1 63 Balance at December 31 (1) $ 3,925 $ 3,831 $ 3,712 $ 900 $ 894 $ 887 $ 2,930 $ 2,847 $ 2,743 (1) Current portion of the ARO for Sempra is included in Other Current Liabilities on the Consolidated Balance Sheets.
Schedule of Changes in Accumulated Other Comprehensive Income by Component	The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, after amounts attributable to NCI. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (Dollars in millions) Foreign Financial Pension and PBOP Total AOCI Sempra: Balance at December 31, 2021 $ (79) $ (156) $ (83) $ (318) OCI before reclassifications 10 147 (11) 146 Amounts reclassified from AOCI (2) 10 19 8 37 Net OCI (2) 20 166 (3) 183 Balance at December 31, 2022 (59) 10 (86) (135) OCI before reclassifications 23 59 (35) 47 Amounts reclassified from AOCI (3) — (66) 4 (62) Net OCI (3) 23 (7) (31) (15) Balance at December 31, 2023 (36) 3 (117) (150) OCI before reclassifications (30) 34 (1) 3 Amounts reclassified from AOCI — (22) 3 (19) Net OCI (30) 12 2 (16) Balance at December 31, 2024 $ (66) $ 15 $ (115) $ (166) SDG&E: Balance at December 31, 2021 $ (10) $ (10) OCI before reclassifications 2 2 Amounts reclassified from AOCI 1 1 Net OCI 3 3 Balance at December 31, 2022 (7) (7) OCI before reclassifications (2) (2) Amounts reclassified from AOCI 1 1 Net OCI (1) (1) Balance at December 31, 2023 (8) (8) OCI before reclassifications (3) (3) Amounts reclassified from AOCI (1) (1) Net OCI (4) (4) Balance at December 31, 2024 $ (12) $ (12) SoCalGas: Balance at December 31, 2021 $ (13) $ (18) $ (31) OCI before reclassifications — 4 4 Amounts reclassified from AOCI 1 2 3 Net OCI 1 6 7 Balance at December 31, 2022 (12) (12) (24) OCI before reclassifications — (1) (1) Amounts reclassified from AOCI 1 1 2 Net OCI 1 — 1 Balance at December 31, 2023 (11) (12) (23) OCI before reclassifications — (5) (5) Amounts reclassified from AOCI 1 — 1 Net OCI 1 (5) (4) Balance at December 31, 2024 $ (10) $ (17) $ (27) (1) All amounts are net of income tax, if subject to tax, and after NCI. (2) Total AOCI includes $9 of foreign currency translation adjustments associated with the sale of NCI to ADIA in 2022. We discuss this transaction in Note 12 in “Noncontrolling Interests – SI Partners.” This transaction did not impact the Consolidated Statement of Comprehensive Income (Loss). (3) Total AOCI includes $(46) of financial instruments associated with sale of NCI to KKR Denali in 2023, which we discuss in Note 12 in “Noncontrolling Interests – SI Partners Subsidiaries.” This transaction did not impact the Consolidated Statement of Comprehensive Income (Loss).
Schedule of Reclassifications out Of Accumulated Other Comprehensive Income	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about AOCI components Amounts reclassified from AOCI Affected line item on Years ended December 31, 2024 2023 2022 Sempra: Foreign currency translation adjustments $ — $ — $ 1 Operation and maintenance Financial instruments: Interest rate instruments $ (11) $ 1 $ 1 Interest expense Interest rate instruments (23) (48) 29 Equity earnings (1) Foreign exchange instruments (5) 1 (1) Revenues: Energy-related businesses (2) 2 1 Other income, net Foreign exchange instruments (6) 2 — Equity earnings (1) Interest rate and foreign exchange instruments — (1) (2) Interest expense — (6) (12) Other income, net Total, before income tax (47) (49) 16 11 6 (6) Income tax expense Total, net of income tax (36) (43) 10 14 23 9 Earnings attributable to noncontrolling interests Total, net of income tax and after NCI $ (22) $ (20) $ 19 Pension and PBOP (2) : Amortization of actuarial loss $ 6 $ 3 $ 7 Other income, net Amortization of prior service cost 3 2 4 Other income, net Settlement charges 9 — — Other income, net Total, before income tax 18 5 11 (15) (1) (3) Income tax expense Total, net of income tax $ 3 $ 4 $ 8 Total reclassifications for the period, net of income tax and after NCI $ (19) $ (16) $ 28 SDG&E: Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ — $ 1 Other income, net Amortization of prior service cost — 1 — Other income, net Total, before income tax 1 1 1 (2) — — Income tax (expense) benefit Total reclassifications for the period, net of income tax $ (1) $ 1 $ 1 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 $ 1 Interest expense Pension and PBOP (2) : Amortization of actuarial loss $ 1 $ 1 $ 2 Other income (expense), net Amortization of prior service cost 1 1 1 Other income (expense), net Total, before income tax 2 2 3 (2) (1) (1) Income tax (expense) benefit Total, net of income tax $ — $ 1 $ 2 Total reclassifications for the period, net of income tax $ 1 $ 2 $ 3 (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” in Note 8).
Schedule of Other Income (expense)	Other Income, Net, on the Consolidated Statements of Operations consists of the following: OTHER INCOME (EXPENSE), NET (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Allowance for equity funds used during construction $ 150 $ 140 $ 143 Investment gains (losses), net (1) 36 28 (42) Gains on interest rate and foreign exchange instruments, net 2 4 11 Foreign currency transaction (losses) gains, net (2) (16) 2 (24) Non-service components of net periodic benefit cost (101) (106) (59) Interest on regulatory balancing accounts, net 75 79 26 Sundry, net (10) (16) (31) Total $ 136 $ 131 $ 24 SDG&E: Allowance for equity funds used during construction $ 73 $ 86 $ 88 Non-service components of net periodic benefit cost 4 (19) (11) Interest on regulatory balancing accounts, net 23 42 18 Sundry, net (10) (12) (3) Total $ 90 $ 97 $ 92 SoCalGas: Allowance for equity funds used during construction $ 72 $ 54 $ 55 Non-service components of net periodic benefit cost (86) (80) (42) Interest on regulatory balancing accounts, net 52 37 8 Sundry, net (13) (15) (29) Total $ 25 $ (4) $ (8) (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 Consolidated Statements of Operations. (2) Includes losses of $11 in 2022 from translation to U.S. dollars of a Mexican peso-denominated loan to IMG, which are offset by corresponding amounts included in Equity Earnings on the Consolidated Statements of Operations.

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 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 Year ended December 31, 2024 By major service line: Utilities $ 11,008 $ 78 $ (23) $ 11,063 Energy-related businesses — 818 (63) 755 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 By market: Gas $ 6,858 $ 471 $ (21) $ 7,308 Electric 4,150 425 (65) 4,510 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 Revenues from contracts with customers $ 11,008 $ 896 $ (86) $ 11,818 Utilities regulatory revenues 374 — — 374 Other revenues — 986 7 993 Total revenues $ 11,382 $ 1,882 $ (79) $ 13,185 Year ended December 31, 2023 By major service line: Utilities $ 13,686 $ 87 $ (19) $ 13,754 Energy-related businesses — 1,164 (70) 1,094 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 By market: Gas $ 8,949 $ 755 $ (17) $ 9,687 Electric 4,737 496 (72) 5,161 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 Revenues from contracts with customers $ 13,686 $ 1,251 $ (89) $ 14,848 Utilities regulatory revenues 75 — — 75 Other revenues — 1,820 (23) 1,797 Total revenues $ 13,761 $ 3,071 $ (112) $ 16,720 Year ended December 31, 2022 By major service line: Utilities $ 11,944 $ 89 $ (15) $ 12,018 Energy-related businesses — 1,760 (56) 1,704 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 By market: Gas $ 7,267 $ 1,270 $ (12) $ 8,525 Electric 4,677 579 (59) 5,197 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 Revenues from contracts with customers $ 11,944 $ 1,849 $ (71) $ 13,722 Utilities regulatory revenues 633 — — 633 Other revenues — 70 14 84 Total revenues $ 12,577 $ 1,919 $ (57) $ 14,439 DISAGGREGATED REVENUES (Dollars in millions) SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 By major service line: Revenues from contracts with customers – Utilities $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 By market: Gas $ 878 $ 1,204 $ 899 $ 6,134 $ 7,857 $ 6,459 Electric 4,164 4,750 4,687 — — — Revenues from contracts with customers $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 Revenues from contracts with customers $ 5,042 $ 5,954 $ 5,586 $ 6,134 $ 7,857 $ 6,459 Utilities regulatory revenues 299 (357) 252 75 432 381 Total revenues $ 5,341 $ 5,597 $ 5,838 $ 6,209 $ 8,289 $ 6,840
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at December 31, 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 December 31, 2024. REMAINING PERFORMANCE OBLIGATIONS (Dollars in millions) Sempra (1) SDG&E 2025 $ 403 $ 4 2026 284 4 2027 285 4 2028 239 4 2029 211 4 Thereafter 2,101 52 Total revenues to be recognized $ 3,523 $ 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 2024, 2023 or 2022. CONTRACT LIABILITIES (Dollars in millions) 2024 2023 2022 Sempra: Contract liabilities at January 1 $ (198) $ (252) (278) Revenue from performance obligations satisfied during reporting period 11 14 131 Payments received in advance (7) (21) (105) Contract modification (2) 61 — Contract liabilities at December 31 (1) $ (196) $ (198) $ (252) SDG&E: Contract liabilities at January 1 $ (75) $ (79) $ (83) Revenue from performance obligations satisfied during reporting period 3 4 4 Contract liabilities at December 31 (2) $ (72) $ (75) $ (79) (1) Balances at December 31, 2024 and 2023 include $105 and $5, respectively, in Other Current Liabilities and $91 and $193, respectively, in Deferred Credits and Other. (2)
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 Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2024 2023 Sempra: Accounts receivable – trade, net (1) $ 1,787 $ 1,951 Accounts receivable – other, net 12 15 Due from unconsolidated affiliates – current (2) 4 4 Other long-term assets (3) 18 — Total $ 1,821 $ 1,970 SDG&E: Accounts receivable – trade, net (1) $ 774 $ 870 Accounts receivable – other, net 11 13 Due from unconsolidated affiliates – current (2) 6 6 Other long-term assets (3) 4 — Total $ 795 $ 889 SoCalGas: Accounts receivable – trade, net $ 932 $ 985 Accounts receivable – other, net 1 2 Other long-term assets (3) 14 — Total $ 947 $ 987 (1) At December 31, 2024 and 2023, includes $144 and $148, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues. (2) Amount is presented net of amounts due to unconsolidated affiliates on the 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)	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
Schedule of Regulatory Assets	We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until 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) AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Fixed-price contracts and other derivatives $ 53 $ 215 $ 11 $ 14 $ 42 $ 201 Deferred income taxes recoverable in rates 1,689 1,142 802 626 817 430 Pension and PBOP plan obligations (458) (212) (2) 48 (456) (260) Employee benefit costs 19 24 3 3 16 21 Removal obligations (3,295) (3,082) (2,676) (2,468) (619) (614) Environmental costs 149 139 115 105 34 34 Sunrise Powerlink fire mitigation 124 124 124 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (313) (233) (313) (233) — — Commodity – gas, including transportation (47) (259) 86 52 (133) (311) Safety and reliability 820 959 227 207 593 752 Public purpose programs (439) (273) (219) (144) (220) (129) 2024 GRC retroactive impacts 631 — 277 — 354 — Wildfire mitigation plan 808 685 808 685 — — Liability insurance premium (24) 113 (15) 90 (9) 23 Other balancing accounts 158 373 (51) (152) 209 525 Other regulatory assets (liabilities), net (2) 164 (10) 87 49 79 (58) Total $ 39 $ (295) $ (736) $ (994) $ 707 $ 614 (1) At December 31, 2024 and 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $1,731 and $1,913, respectively, for SDG&E was $873 and $950, respectively, and for SoCalGas was $858 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	We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until 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) AT DECEMBER 31 (Dollars in millions) Sempra SDG&E SoCalGas 2024 2023 2024 2023 2024 2023 Fixed-price contracts and other derivatives $ 53 $ 215 $ 11 $ 14 $ 42 $ 201 Deferred income taxes recoverable in rates 1,689 1,142 802 626 817 430 Pension and PBOP plan obligations (458) (212) (2) 48 (456) (260) Employee benefit costs 19 24 3 3 16 21 Removal obligations (3,295) (3,082) (2,676) (2,468) (619) (614) Environmental costs 149 139 115 105 34 34 Sunrise Powerlink fire mitigation 124 124 124 124 — — Regulatory balancing accounts (1)(2) : Commodity – electric (313) (233) (313) (233) — — Commodity – gas, including transportation (47) (259) 86 52 (133) (311) Safety and reliability 820 959 227 207 593 752 Public purpose programs (439) (273) (219) (144) (220) (129) 2024 GRC retroactive impacts 631 — 277 — 354 — Wildfire mitigation plan 808 685 808 685 — — Liability insurance premium (24) 113 (15) 90 (9) 23 Other balancing accounts 158 373 (51) (152) 209 525 Other regulatory assets (liabilities), net (2) 164 (10) 87 49 79 (58) Total $ 39 $ (295) $ (736) $ (994) $ 707 $ 614 (1) At December 31, 2024 and 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $1,731 and $1,913, respectively, for SDG&E was $873 and $950, respectively, and for SoCalGas was $858 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 Regulated Operations	The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets. WILDFIRE FUND (Dollars in millions) December 31, Location 2024 2023 Wildfire Fund asset: Current Prepaid Expenses $ 14 $ 28 Noncurrent Wildfire Fund 262 269 Wildfire Fund obligation: Current Other Current Liabilities 13 13 Noncurrent Deferred Credits and Other 31 42 The following table summarizes the cost of capital for SDG&E and SoCalGas. The authorized weighting remained unchanged for each of the years presented. AUTHORIZED COST OF CAPITAL Authorized weighting 2022 2023 2024 2025 2022 2023 (1) 2024 2025 Return on rate base Weighted return on rate base SDG&E: Long-Term Debt 45.25 % 4.59 % 4.05 % 4.34 % 4.34 % 2.08 % 1.83 % 1.96 % 1.96 % Preferred Equity 2.75 6.22 6.22 6.22 6.22 0.17 0.17 0.17 0.17 Common Equity 52.00 10.20 9.95 10.65 10.23 5.30 5.17 5.54 5.32 100.00 % 7.55 % 7.18 % 7.67 % 7.45 % SoCalGas: Long-Term Debt 45.60 % 4.23 % 4.07 % 4.54 % 4.63 % 1.93 % 1.86 % 2.07 % 2.11 % Preferred Equity 2.40 6.00 6.00 6.00 6.00 0.14 0.14 0.14 0.14 Common Equity 52.00 10.05 9.80 10.50 10.08 5.23 5.10 5.46 5.24 100.00 % 7.30 % 7.10 % 7.67 % 7.49 % (1) Total weighted return on rate base for SDG&E does not sum due to rounding differences.

SEMPRA _ INVESTMENTS IN UNCON_2

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2024
Investments [Abstract]
Equity Method Investments	We provide the carrying values of our investments and earnings on these investments by segment in the following tables. EQUITY METHOD AND OTHER INVESTMENTS (1) (Dollars in millions) Percent ownership Investment balance December 31, 2024 2023 2024 2023 Sempra Texas Utilities: Oncor Holdings (2) 100 % 100 % $ 15,400 $ 14,266 Sempra Texas Utilities: Sharyland Holdings (3) 50 % 50 % $ 122 $ 114 Sempra Infrastructure: Cameron LNG JV (4) 50.2 50.2 1,149 1,008 IMG (5) 40 40 723 620 TAG Norte (6) 50 50 539 501 Segment totals 2,533 2,243 Parent and other – Other 1 1 Total $ 2,534 $ 2,244 (1) All amounts are before NCI, where applicable. (2) The carrying value of our equity method investment is $2,884 and $2,870 higher than the underlying equity in the net assets of the investee at December 31, 2024 and 2023, respectively, due to $2,868 of equity method goodwill and $69 in basis differences in AOCI, offset by $53 and $67 at December 31, 2024 and 2023, respectively, due to a tax sharing liability to TTI under a tax sharing agreement. (3) The carrying value of our equity method investment is $41 higher than the underlying equity in the net assets of the investee due to equity method goodwill. (4) The carrying value of our equity method investment is $257 and $262 higher than the underlying equity in the net assets of the investee at December 31, 2024 and 2023, respectively, primarily due to guarantees, interest capitalized on the investment prior to the JV commencing its operations, and amortization of guarantee fees and capitalized interest thereafter. (5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees. (6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill. EARNINGS FROM EQUITY METHOD INVESTMENTS (1) (Dollars in millions) Years ended December 31, 2024 2023 2022 EARNINGS RECORDED BEFORE INCOME TAX (2) : Sempra Texas Utilities: Sharyland Holdings $ 8 $ 7 $ 7 Sempra Infrastructure: Cameron LNG JV (3) 576 586 659 Segment totals 584 593 666 Parent and other – RBS Sempra Commodities LLP 19 40 — 603 633 666 EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 780 694 735 Sempra Infrastructure: IMG 136 40 68 TAG Norte 90 114 29 Segment totals 1,006 848 832 Total $ 1,609 $ 1,481 $ 1,498 (1) All amounts are before NCI, where applicable. (2) We provide our ETR calculation in Note 7. (3) We provide the contributions to and distributions from our investments by segment in the following tables. EXPENDITURES FOR INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra Texas Utilities: Oncor Holdings $ 972 $ 363 $ 341 Sharyland Holdings 4 4 5 976 367 346 Sempra Infrastructure: Cameron LNG JV 12 15 30 12 15 30 Total $ 988 $ 382 $ 376 DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra Texas Utilities: Oncor Holdings (1) $ 616 $ 441 $ 340 Sharyland Holdings 4 4 5 620 445 345 Sempra Infrastructure: Cameron LNG JV 453 456 509 IMG 33 11 — TAG Norte 62 36 32 548 503 541 Segment totals 1,168 948 886 Parent and other – RBS Sempra Commodities LLP 9 — — Total $ 1,177 $ 948 $ 886 (1) Includes a $13 noncash return on investment in 2024. When including payments received under a tax sharing agreement, cash and noncash distributions would total $681, $558 and $443 in 2024, 2023 and 2022, respectively.
Schedule of Summarized Financial Information	We provide summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Years ended December 31, 2024 2023 2022 Operating revenues $ 6,082 $ 5,586 $ 5,243 Operating expenses (4,318) (4,026) (3,682) Income from operations 1,764 1,560 1,561 Interest expense (653) (536) (445) Income tax expense (217) (192) (203) Net income 957 849 893 NCI held by TTI (192) (170) (179) Earnings attributable to Sempra (1) 765 679 714 December 31, 2024 2023 Current assets $ 1,638 $ 1,431 Noncurrent assets 38,697 34,649 Current liabilities 2,183 1,625 Noncurrent liabilities 21,958 19,727 NCI held by TTI 3,689 3,338 (1) Excludes adjustments to equity earnings related to amortization of a tax sharing liability associated with a tax sharing agreement and changes in basis differences in AOCI within the carrying value of our equity method investment. We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings and RBS Sempra Commodities LLP) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Gross revenues $ 2,962 $ 3,083 $ 2,959 Operating expenses (820) (776) (772) Income from operations 2,142 2,307 2,187 Interest expense (547) (570) (505) Net income/Earnings (1)(2) 1,688 1,499 1,537 December 31, 2024 2023 Current assets $ 1,134 $ 1,216 Noncurrent assets 14,687 14,826 Current liabilities 1,130 1,255 Noncurrent liabilities 10,051 10,786 (1) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships. (2) Amounts for Cameron LNG JV exclude adjustments to equity earnings related to amortization of capitalized interest and guarantee fees within the carrying value of our equity method investment and changes in basis differences in equity earnings related to AOCI.

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	COMMITTED LINES OF CREDIT (Dollars in millions) December 31, 2024 Borrower Expiration date of facility Total facility Commercial Amounts outstanding Letters of credit outstanding Available unused credit Sempra October 2029 $ 4,000 $ — $ — $ — $ 4,000 SDG&E October 2029 1,500 (417) — — 1,083 SoCalGas October 2029 1,200 (337) — — 863 SI Partners and IEnova September 2025 500 — (368) — 132 SI Partners and IEnova August 2026 1,000 — — — 1,000 SI Partners and IEnova August 2028 1,500 — (186) — 1,314 Port Arthur LNG March 2030 200 — — (64) 136 Total $ 9,900 $ (754) $ (554) $ (64) $ 8,528 UNCOMMITTED LETTERS OF CREDIT OUTSTANDING (Dollars in millions) Expiration date range December 31, 2024 SDG&E January 2025 - November 2025 $ 26 SoCalGas January 2025 - December 2025 20 Other Sempra January 2025 - November 2054 451 Total Sempra $ 497 The weighted-average interest rates on all short-term debt were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2024 2023 Sempra 5.03 % 5.96 % SDG&E 4.76 — SoCalGas 5.02 5.44
Schedule of Long-term Debt	The following tables show the detail and maturities of long-term debt outstanding. LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2024 2023 SDG&E: First mortgage bonds (collateralized by plant assets): 2.50% May 15, 2026 $ 500 $ 500 6.00% June 1, 2026 250 250 4.95% August 15, 2028 600 600 1.70% October 1, 2030 800 800 3.00% March 15, 2032 500 500 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 6.00% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.50% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.30% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.10% June 15, 2049 400 400 3.32% April 15, 2050 400 400 2.95% August 15, 2051 750 750 3.70% March 15, 2052 500 500 5.35% April 1, 2053 800 800 5.55% April 15, 2054 600 — 8,950 8,350 Other long-term debt (uncollateralized): Notes at variable rates (5.99% at December 31, 2023) February 18, 2024 (1) — 400 Finance lease obligations: Power purchase agreements 1,138 1,166 Other 67 67 1,205 1,633 10,155 9,983 Current portion of long-term debt and finance leases (42) (441) Unamortized discount on long-term debt (33) (29) Unamortized debt issuance costs (62) (60) Total SDG&E $ 10,018 $ 9,453 (1) Callable long-term debt not subject to make-whole provisions. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ — $ 500 3.20% June 15, 2025 350 350 2.60% June 15, 2026 500 500 2.55% February 1, 2030 650 650 5.20% June 1, 2033 500 500 5.05% September 1, 2034 600 — 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.30% January 15, 2049 550 550 3.95% February 15, 2050 350 350 6.35% November 15, 2052 600 600 5.75% June 1, 2053 500 500 5.60% April 1, 2054 500 — 6,650 6,050 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 2.95% Notes April 15, 2027 700 700 5.67% Notes January 18, 2028 (2) 5 5 Finance lease obligations 110 107 819 816 7,469 6,866 Current portion of long-term debt and finance leases (373) (523) Unamortized discount on long-term debt (18) (13) Unamortized debt issuance costs (47) (42) Total SoCalGas $ 7,031 $ 6,288 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 Other Sempra: Sempra - Other long-term debt (uncollateralized): 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Sempra Infrastructure - Other long-term debt (uncollateralized unless otherwise noted): Loan at variable rates (weighted-average rate of 7.29% and 8.31% at December 31, 2024 and 2023, respectively) December 9, 2025 1,063 832 3.75% Notes January 14, 2028 300 300 Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets (1) 1,090 258 3.25% Notes January 15, 2032 400 400 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable June 15, 2022 through November 19, 2034 (1) 90 96 2.90% Loan payable June 15, 2022 through November 19, 2034 (1) 219 231 4.875% Notes January 14, 2048 540 540 4.75% Notes January 15, 2051 800 800 4,682 3,649 16,590 12,207 Current portion of long-term debt (1,859) (11) Unamortized discount on long-term debt (78) (66) Unamortized debt issuance costs (144) (112) Total Other Sempra 14,509 12,018 Total Sempra $ 31,558 $ 27,759 (1) Callable long-term debt not subject to make-whole provisions. The following table shows the detail and maturities of uncollateralized long-term debt outstanding. LONG-TERM DEBT (Dollars in millions) December 31, 2024 2023 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Current portion of long-term debt (750) — Unamortized discount on long-term debt (30) (29) Unamortized debt issuance costs (100) (68) Total long-term debt $ 11,028 $ 8,461 (1) Callable long-term debt not subject to make-whole provisions.
Schedule of Maturities of Long-term Debt	At December 31, 2024, scheduled maturities of long-term debt are as follows: MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Total 2025 $ — $ 350 $ 1,862 $ 2,212 2026 750 504 599 1,853 2027 — 700 799 1,499 2028 600 5 1,358 1,963 2029 — — 584 584 Thereafter 7,600 5,800 11,388 24,788 Total $ 8,950 $ 7,359 $ 16,590 $ 32,899 (1)
Schedule of Callable Long Term Debt	At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2024 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ — $ 4 $ 6,687 $ 6,691 Subject to make-whole provisions 8,950 7,350 9,903 26,203

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Income tax expense $ 219 $ 490 $ 556 Income before income taxes and equity earnings $ 2,110 $ 2,627 $ 1,343 Equity earnings, before income tax (1) 603 633 666 Pretax income $ 2,713 $ 3,260 $ 2,009 Effective income tax rate 8 % 15 % 28 % SDG&E: Income tax expense (benefit) $ 153 $ (26) $ 182 Income before income taxes $ 1,044 $ 910 $ 1,097 Effective income tax rate 15 % (3) % 17 % SoCalGas: Income tax expense (benefit) $ 31 $ (5) $ 138 Income before income taxes $ 987 $ 807 $ 738 Effective income tax rate 3 % (1) % 19 % (1) We discuss how we recognize equity earnings in Note 5. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2024 2023 2022 Sempra: U.S. federal statutory income tax rate 21 % 21 % 21 % Valuation allowances 14 — (2) Utility depreciation 4 3 4 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (2) 1 1 3 State income taxes, net of federal income tax benefit 1 1 1 Outside basis differences — — 6 Remeasurement of deferred taxes — (1) (3) Tax credits (1) (5) (1) Utility self-developed software expenditures (1) (1) — Allowance for equity funds used during construction (1) (1) (1) Amortization of excess deferred income taxes (1) (1) (2) Resolution of prior years’ income tax items (2) (2) (2) Noncontrolling interests (3) (3) — Utility repairs expenditures (8) (6) (5) Foreign exchange and inflation effects (1) (14) 9 9 Other, net (2) — — Effective income tax rate 8 % 15 % 28 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 5 3 State income taxes, net of federal income tax benefit 3 2 4 Self-developed software expenditures (1) (1) — Resolution of prior years’ income tax items (1) (1) (2) Amortization of excess deferred income taxes (1) (2) (2) Allowance for equity funds used during construction (1) (2) (2) Tax credits (1) (16) — Repairs expenditures (9) (8) (5) Other, net — (1) — Effective income tax rate 15 % (3) % 17 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 5 5 Nondeductible expenditures — — 2 State income taxes, net of federal income tax benefit (1) (2) 2 Amortization of excess deferred income taxes (1) (2) (2) Allowance for equity funds used during construction (2) (1) (2) Self-developed software expenditures (2) (2) — Resolution of prior years’ income tax items (3) (6) — Repairs expenditures (14) (14) (6) Other, net — — (1) Effective income tax rate 3 % (1) % 19 % (1) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. (2) Related to operations in Mexico.
Schedule Of Geographic Components Of Income Before Income Taxes And Equity Earnings Of Certain Unconsolidated Subsidiaries	The table below presents the geographic location of pretax income. PRETAX INCOME BY GEOGRAPHIC LOCATION (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: U.S. $ 2,354 $ 2,678 $ 1,449 Non-U.S. 359 582 560 Total (1) $ 2,713 $ 3,260 $ 2,009 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the calculation of pretax income.
Schedule Of Components Of Income Tax Expense	The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Current: U.S. federal $ 73 $ 102 $ — U.S. state (4) 3 (1) Non-U.S. 179 208 165 Total 248 313 164 Deferred: U.S. federal 366 (56) 248 U.S. state 28 18 50 Non-U.S. (422) 225 94 Total (1) (28) 187 392 Deferred investment tax credits (1) (10) — Total income tax expense $ 219 $ 490 $ 556 SDG&E: Current: U.S. federal $ (16) $ (156) $ 76 U.S. state — (5) 13 Total (16) (161) 89 Deferred: U.S. federal 129 111 54 U.S. state 41 35 38 Total 170 146 92 Deferred investment tax credits (1) (11) 1 Total income tax expense (benefit) $ 153 $ (26) $ 182 SoCalGas: Current: U.S. federal $ 3 $ (6) $ (5) U.S. state — (11) (3) Total 3 (17) (8) Deferred: U.S. federal 45 22 125 U.S. state (16) (11) 22 Total 29 11 147 Deferred investment tax credits (1) 1 (1) Total income tax expense (benefit) $ 31 $ (5) $ 138 (1) In 2024 and 2023, Deferred Income Taxes and Investment Tax Credits on the Sempra Consolidated Statements of Cash Flows also includes $9 and $72, respectively, of income taxes included in equity earnings, which are recorded net of income tax under a tax sharing agreement with Oncor.
Schedule Of Components Of Deferred Tax Assets And Liabilities	The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES (Dollars in millions) December 31, 2024 2023 Sempra: Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 7,164 $ 6,875 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 79 55 Regulatory balancing accounts 850 727 Right-of-use assets – operating leases 325 211 Property taxes 74 68 Postretirement benefits 150 47 Other deferred income tax liabilities 94 68 Total deferred income tax liabilities 8,736 8,051 Deferred income tax assets: Tax credits 1,485 1,468 Net operating losses 1,105 982 Compensation-related items 225 157 Operating lease liabilities 301 179 Other deferred income tax assets 219 96 Bad debt allowance 151 144 Accrued expenses not yet deductible 80 89 Deferred income tax assets before valuation allowances 3,566 3,115 Less: valuation allowances 503 189 Total deferred income tax assets 3,063 2,926 Net deferred income tax liability (2) $ 5,673 $ 5,125 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2024 and 2023, includes $172 and $129, respectively, recorded as a noncurrent asset and $5,845 and $5,254, respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES (Dollars in millions) SDG&E SoCalGas December 31, 2024 2023 2024 2023 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 2,805 $ 2,641 $ 2,594 $ 2,272 Regulatory balancing accounts 545 418 306 309 Right-of-use assets – operating leases 222 103 5 8 Property taxes 47 43 27 25 Postretirement benefits — — 124 71 Other deferred income tax liabilities — — 2 4 Total deferred income tax liabilities 3,619 3,205 3,058 2,689 Deferred income tax assets: Tax credits 8 7 2 7 Compensation-related items 8 9 26 31 Operating lease liabilities 222 103 5 8 Bad debt allowance 29 37 72 86 Accrued expenses not yet deductible 10 11 54 56 Net operating losses 122 146 874 890 Other deferred income tax assets 9 19 20 25 Total deferred income tax assets 408 332 1,053 1,103 Net deferred income tax liability $ 3,211 $ 2,873 $ 2,005 $ 1,586
Summary of Tax Credit Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2024 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,091 2037 General business tax credits (1) 126 2043 Corporate alternative minimum tax credits (1) 676 Indefinite Foreign tax credits (2) 706 2025 U.S. state: NOLs (2) 5,912 2027 General business tax credits (1) 24 2027 Non-U.S. (2) : NOLs 782 2025 Foreign tax credits 5 Indefinite SDG&E: U.S. federal (1) : NOLs $ 279 Indefinite General business tax credits 1 2044 U.S. state NOLs (1) 909 2043 SoCalGas: U.S. federal NOLs (1) $ 2,857 Indefinite U.S. state NOLs (1) 3,917 2042 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as we discuss below.
Summary of Operating Loss Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2024 Year expiration begins Sempra: U.S. federal: NOLs (1) $ 3,091 2037 General business tax credits (1) 126 2043 Corporate alternative minimum tax credits (1) 676 Indefinite Foreign tax credits (2) 706 2025 U.S. state: NOLs (2) 5,912 2027 General business tax credits (1) 24 2027 Non-U.S. (2) : NOLs 782 2025 Foreign tax credits 5 Indefinite SDG&E: U.S. federal (1) : NOLs $ 279 Indefinite General business tax credits 1 2044 U.S. state NOLs (1) 909 2043 SoCalGas: U.S. federal NOLs (1) $ 2,857 Indefinite U.S. state NOLs (1) 3,917 2042 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as we discuss below.
Summary of Valuation Allowance	The following table provides the valuation allowances that we recorded against a portion of our total deferred income tax assets shown above in the “Deferred Income Taxes – Sempra” table. VALUATION ALLOWANCES BY JURISDICTION (Dollars in millions) December 31, 2024 2023 Sempra: U.S. federal $ 406 $ 108 U.S. state 47 51 Non-U.S. 50 30 $ 503 $ 189
Schedule of Unrecognized Tax Benefits Roll Forward	Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2024 2023 2022 Sempra: Balance at January 1 $ 492 $ 278 $ 304 Increase in prior period tax positions 40 308 16 Decrease in prior period tax positions (8) (63) (2) Decrease in current period tax positions — (21) — Settlements with tax authorities (15) (16) (43) Expiration of statutes of limitations — — (1) Increase in current period tax positions 39 6 4 Balance at December 31 $ 548 $ 492 $ 278 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (229) $ (224) $ (117) increase the effective tax rate (1) 1 1 38 SDG&E: Balance at January 1 $ 14 $ 14 $ 14 Increase in prior period tax positions — 2 — Settlements with tax authorities — (2) — Balance at December 31 $ 14 $ 14 $ 14 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (11) $ (11) $ (11) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 29 $ 77 $ 72 Increase in prior period tax positions — 1 1 Decrease in prior period tax positions — (47) — Increase in current period tax positions — — 4 Settlements with tax authorities — (2) — Balance at December 31 $ 29 $ 29 $ 77 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (29) $ (29) $ (67) increase the effective tax rate (1) — — 37 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above.
Summary of Income Tax Contingencies	It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) December 31, 2024 2023 2022 Sempra: Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities $ 15 $ 242 $ 8 SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 6 $ 6 $ 6 SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ 2 $ 2 $ 2

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
Schedule Of Defined Benefit Plans, Change In Benefit Obligation And Fair Value Of Plan Assets	The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2024 and 2023, and a statement of the funded status at December 31, 2024 and 2023. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP 2024 2023 2024 2023 Sempra: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 3,107 $ 2,806 $ 693 $ 663 Service cost 132 109 15 13 Interest cost 166 157 36 37 Contributions from plan participants — — 23 23 Actuarial (gain) loss (100) 190 (11) 28 Plan amendments 2 4 — — Benefit payments (81) (83) (69) (71) Settlements (87) (76) — — Obligation at December 31 3,139 3,107 687 693 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,664 2,390 1,169 1,096 Actual return on plan assets 196 218 57 117 Employer contributions 243 215 5 4 Contributions from plan participants — — 23 23 Benefit payments (81) (83) (69) (71) Settlements (87) (76) — — Fair value of plan assets at December 31 2,935 2,664 1,185 1,169 Funded status at December 31 $ (204) $ (443) $ 498 $ 476 Net recorded (liability) asset at December 31 $ (204) $ (443) $ 498 $ 476 (1) The accumulated benefit obligation was $2,900 and $2,865 at December 31, 2024 and 2023, respectively. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP 2024 2023 2024 2023 SDG&E: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 807 $ 714 $ 140 $ 134 Service cost 39 32 3 3 Interest cost 43 40 7 8 Contributions from plan participants — — 8 8 Actuarial (gain) loss (28) 69 (6) 7 Benefit payments (16) (17) (18) (20) Settlements (23) (31) — — Obligation at December 31 822 807 134 140 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 726 670 150 147 Actual return on plan assets 63 52 5 14 Employer contributions 37 52 — 1 Contributions from plan participants — — 8 8 Benefit payments (16) (17) (18) (20) Settlements (23) (31) — — Fair value of plan assets at December 31 787 726 145 150 Funded status at December 31 $ (35) $ (81) $ 11 $ 10 Net recorded (liability) asset at December 31 $ (35) $ (81) $ 11 $ 10 (1) The accumulated benefit obligation was $781 and $769 at December 31, 2024 and 2023, respectively. PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Dollars in millions) Pension (1) PBOP (Dollars in millions) 2024 2023 2024 2023 SoCalGas: CHANGE IN PROJECTED BENEFIT OBLIGATION Obligation at January 1 $ 1,977 $ 1,814 $ 521 $ 497 Service cost 79 65 11 9 Interest cost 105 101 27 28 Contributions from plan participants — — 14 14 Actuarial (gain) loss (70) 90 (4) 21 Plan amendments 2 — — — Benefit payments (56) (58) (47) (48) Settlements (38) (35) — — Obligation at December 31 1,999 1,977 522 521 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,744 1,535 990 923 Actual return on plan assets 115 151 50 100 Employer contributions 172 151 1 1 Contributions from plan participants — — 14 14 Benefit payments (56) (58) (47) (48) Settlements (38) (35) — — Fair value of plan assets at December 31 1,937 1,744 1,008 990 Funded status at December 31 $ (62) $ (233) $ 486 $ 469 Net recorded (liability) asset at December 31 $ (62) $ (233) $ 486 $ 469 (1) The accumulated benefit obligation was $1,824 and $1,799 at December 31, 2024 and 2023, respectively.
Schedule Of Defined Benefit Plans, Amounts Recognized In Balance Sheet	The net (liability) asset is included in the following categories on the Consolidated Balance Sheets. PENSION AND PBOP OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Noncurrent assets $ 6 $ — $ 507 $ 485 Current liabilities (50) (44) (1) (1) Noncurrent liabilities (160) (399) (8) (8) Net recorded (liability) asset $ (204) $ (443) $ 498 $ 476 SDG&E: Noncurrent assets $ — $ — $ 11 $ 10 Current liabilities (7) (2) — — Noncurrent liabilities (28) (79) — — Net recorded (liability) asset $ (35) $ (81) $ 11 $ 10 SoCalGas: Noncurrent assets $ — $ — $ 486 $ 469 Current liabilities (17) (2) — — Noncurrent liabilities (45) (231) — — Net recorded (liability) asset $ (62) $ (233) $ 486 $ 469
Schedule Of Defined Benefit Plans, Amounts In Accumulated Other Comprehensive Income	Amounts recorded in AOCI, net of income tax effects and amounts recorded as regulatory assets, are as follows. AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Net actuarial (loss) gain $ (120) $ (124) $ 14 $ 13 Prior service cost (9) (6) — — Total $ (129) $ (130) $ 14 $ 13 SDG&E: Net actuarial loss $ (12) $ (8) Total $ (12) $ (8) SoCalGas: Net actuarial loss $ (14) $ (10) Prior service cost (3) (2) Total $ (17) $ (12)
Schedule Of Defined Benefit Plans, Pension Plans With Benefit Obligations In Excess Of Plan Assets	The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets. OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Projected benefit obligation $ 2,752 $ 2,925 Accumulated benefit obligation 2,542 2,712 Fair value of plan assets 2,724 2,664 SDG&E: Projected benefit obligation $ 793 $ 781 Accumulated benefit obligation 755 746 Fair value of plan assets 787 726 SoCalGas: Projected benefit obligation $ 1,959 $ 1,944 Accumulated benefit obligation 1,787 1,771 Fair value of plan assets 1,937 1,744 We also have unfunded pension plans at Sempra, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans. OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Projected benefit obligation $ 183 $ 182 Accumulated benefit obligation 159 153 SDG&E: Projected benefit obligation $ 29 $ 26 Accumulated benefit obligation 26 23 SoCalGas: Projected benefit obligation $ 40 $ 33 Accumulated benefit obligation 37 28 Sempra, SDG&E and SoCalGas each have a funded PBOP plan. At December 31, 2024, Sempra’s, SDG&E’s and SoCalGas’ plan assets were each in excess of their respective obligations for funded PBOP plans with accumulated postretirement benefit obligations. We also have unfunded PBOP plans at Sempra. The following table shows the obligations of unfunded PBOP plans. OBLIGATIONS OF UNFUNDED PBOP PLANS (Dollars in millions) December 31, 2024 2023 Sempra: Accumulated postretirement benefit obligation $ 9 $ 9
Schedule of Net Periodic Costs and Amounts Recognized in OCI	The following tables provide the components of net periodic benefit cost (which, other than the service cost component, are included in Other Income, Net) and pretax amounts recognized in OCI. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 Sempra: NET PERIODIC BENEFIT COST Service cost $ 132 $ 109 $ 146 $ 15 $ 13 $ 23 Interest cost 166 157 118 36 37 28 Expected return on plan assets (178) (169) (183) (70) (69) (64) Amortization of: Prior service cost (credit) 5 5 10 (2) (2) (2) Actuarial loss (gain) 14 10 25 (17) (23) (15) Settlement charges 9 — 28 — — — Net periodic benefit cost (credit) 148 112 144 (38) (44) (30) Regulatory adjustment 100 117 84 38 43 30 Total expense (income) recognized 248 229 228 — (1) — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net (gain) loss (2) 42 12 (1) (2) (4) Prior service cost 3 4 — — — — Amortization of actuarial (loss) gain (7) (5) (8) 1 2 1 Amortization of prior service cost (3) (2) (4) — — — Settlements (9) — — — — — Total recognized in OCI (18) 39 — — — (3) Total recognized in net periodic benefit cost and OCI $ 230 $ 268 $ 228 $ — $ (1) $ (3) NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 SDG&E: NET PERIODIC BENEFIT COST Service cost $ 39 $ 32 $ 37 $ 3 $ 3 $ 5 Interest cost 43 40 26 7 8 6 Expected return on plan assets (45) (39) (46) (9) (8) (10) Amortization of: Prior service cost 1 1 1 — — — Actuarial loss (gain) 8 4 1 (1) (2) (2) Settlement charges — — 14 — — — Net periodic benefit cost (credit) 46 38 33 — 1 (1) Regulatory adjustment (8) 15 20 — — 1 Total expense recognized 38 53 53 $ — $ 1 $ — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 4 3 (3) Amortization of actuarial loss (1) — (1) Amortization of prior service cost — (1) — Total recognized in OCI 3 2 (4) Total recognized in net periodic benefit cost and OCI $ 41 $ 55 $ 49 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Dollars in millions) Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 SoCalGas: NET PERIODIC BENEFIT COST Service cost $ 79 $ 65 $ 96 $ 11 $ 9 $ 17 Interest cost 105 101 81 27 28 21 Expected return on plan assets (121) (119) (126) (59) (59) (53) Amortization of: Prior service cost (credit) 4 4 8 (3) (2) (2) Actuarial loss (gain) 1 1 18 (14) (19) (12) Settlement charges — — 14 — — — Net periodic benefit cost (credit) 68 52 91 (38) (43) (29) Regulatory adjustment 108 102 64 38 43 29 Total expense recognized 176 154 155 $ — $ — $ — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 4 2 (5) Prior service cost 2 — — Amortization of actuarial loss (1) (1) (2) Amortization of prior service cost (1) (1) (1) Total recognized in OCI 4 — (8) Total recognized in net periodic benefit cost and OCI $ 180 $ 154 $ 147
Schedule of Assumptions Used	The significant assumptions affecting projected benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE PROJECTED BENEFIT OBLIGATION Pension PBOP December 31, 2024 2023 2024 2023 Sempra: Discount rate 5.74 % 5.31 % 5.75 % 5.34 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 5.75 % 5.30 % 5.75 % 5.30 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 SoCalGas: Discount rate 5.70 % 5.25 % 5.75 % 5.35 % Interest crediting rate (1)(2) 4.54 4.66 4.54 4.66 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for PBOP applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST Pension PBOP Years ended December 31, 2024 2023 2022 2024 2023 2022 Sempra: Discount rate 5.31 % 5.63 % 3.04 % 5.34 % 5.65 % 3.04 % Expected return on plan assets 6.56 6.48 6.27 5.90 5.51 4.77 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 5.30 % 5.60 % 2.99 % 5.30 % 5.65 % 3.05 % Expected return on plan assets 6.25 6.00 5.50 5.88 5.52 4.80 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 3.50-10.00 SoCalGas: Discount rate 5.25 % 5.60 % 3.04 % 5.35 % 5.65 % 3.05 % Expected return on plan assets 6.75 6.75 6.75 5.86 5.47 4.71 Interest crediting rate (1)(2) 4.66 3.99 1.94 4.66 3.99 1.94 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for PBOP applies only to interest bearing health retirement accounts at SDG&E and SoCalGas.
Schedule of Health Care Cost Trend Rates	Assumed health care cost trend rates have a significant effect on the amounts that Sempra, SDG&E and SoCalGas report for the health care plan costs. Following are the health care cost trend rates applicable to our PBOP plans: ASSUMED HEALTH CARE COST TREND RATES PBOP Pre-65 retirees Retirees aged 65 years and older Years ended December 31, 2024 2023 2022 2024 2023 2022 Health care cost trend rate assumed for next year 6.50 % 6.00 % 6.00 % 4.50 % 4.50 % 4.50 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2030 2028 2028 2022 2022 2022
Schedule of Target Asset Allocations	The target asset allocations for Sempra’s pension plans are between return-seeking assets (i.e., generally, equity securities, diversified real assets, high-yield fixed income securities and other instruments with a similar risk profile) and risk-mitigating assets (i.e., generally, government and corporate fixed income securities) as follows: TARGET ASSET ALLOCATIONS FOR PENSION PLANS (Dollars in millions) Sempra SDG&E SoCalGas Return-seeking assets 34 % 42 % 49 % Risk-mitigating assets 66 % 58 % 51 % TARGET ASSET ALLOCATIONS FOR PBOP PLANS (Dollars in millions) Sempra SDG&E and SoCalGas Assets held in pension master trust Assets held in pension master trust Assets held in Voluntary Employee Beneficiary Association trusts Return-seeking assets 74 % 38 % 30 % Risk-mitigating assets 26 % 62 % 70 %
Schedule Of Defined Benefit Plans, Fair Value Of Plan Assets By Level In Fair Value Hierarchy	The fair values by asset category are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 2 $ — $ 2 Equity securities: Domestic 9 — 9 International 5 — 5 Registered investment companies – Domestic 48 — 48 Fixed income securities: Domestic government and government agencies 227 5 232 International government bonds — 3 3 Domestic corporate bonds — 65 65 International corporate bonds — 8 8 Derivative financial instruments 6 — 6 Total investment assets in the fair value hierarchy 297 81 378 Accounts receivable/payable, net 3 Investments measured at NAV – Common/collective trusts 406 Total SDG&E investment assets 787 SoCalGas: Cash and cash equivalents 8 — 8 Equity securities: Domestic 27 — 27 International 14 — 14 Registered investment companies – Domestic 149 — 149 Fixed income securities: Domestic government and government agencies 270 17 287 International government bonds — 9 9 Domestic corporate bonds — 201 201 International corporate bonds — 26 26 Derivative financial instruments (4) 1 (3) Total investment assets in the fair value hierarchy 464 254 718 Accounts receivable/payable, net 22 Investments measured at NAV – Common/collective trusts 1,197 Total SoCalGas investment assets 1,937 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total Other Sempra: Equity securities: Domestic $ 2 $ — $ 2 International 1 — 1 Registered investment companies – Domestic 10 — 10 Fixed income securities: Domestic government and government agencies 77 3 80 International government bonds — 1 1 Domestic corporate bonds — 14 14 International corporate bonds — 2 2 Derivative financial instruments 1 — 1 Total investment assets in the fair value hierarchy 91 20 111 Accounts receivable/payable, net 1 Investments measured at NAV – Common/collective trusts 99 Total Other Sempra investment assets 211 Total Sempra investment assets in the fair value hierarchy $ 852 $ 355 Total Sempra investment assets $ 2,935 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 17 $ — $ 17 Equity securities: Domestic 103 — 103 International 40 — 40 Registered investment companies – Domestic 41 — 41 Fixed income securities: Domestic government and government agencies 240 5 245 International government bonds — 2 2 Domestic corporate bonds — 62 62 International corporate bonds — 8 8 Derivative financial instruments (15) — (15) Total investment assets in the fair value hierarchy 426 77 503 Accounts receivable/payable, net 1 Investments measured at NAV: Common/collective trusts 214 Other 8 Total SDG&E investment assets 726 SoCalGas: Cash and cash equivalents 3 — 3 Equity securities: Domestic 353 1 354 International 137 — 137 Registered investment companies – Domestic 141 1 142 Fixed income securities: Domestic government and government agencies 310 16 326 International government bonds — 5 5 Domestic corporate bonds — 212 212 International corporate bonds — 27 27 Derivative financial instruments 11 — 11 Total investment assets in the fair value hierarchy 955 262 1,217 Accounts receivable/payable, net (12) Investments measured at NAV: Common/collective trusts 513 Other 26 Total SoCalGas investment assets 1,744 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total Other Sempra: Cash and cash equivalents $ 7 $ — $ 7 Equity securities: Domestic 22 1 23 International 8 — 8 Registered investment companies – Domestic 8 — 8 Fixed income securities: Domestic government and government agencies 78 2 80 Domestic corporate bonds — 13 13 International corporate bonds — 2 2 Derivative financial instruments (5) — (5) Total investment assets in the fair value hierarchy 118 18 136 Investments measured at NAV: Common/collective trusts 56 Other 2 Total Other Sempra investment assets 194 Total Sempra investment assets in the fair value hierarchy $ 1,499 $ 357 Total Sempra investment assets $ 2,664 The fair values by asset category of the PBOP plan assets held in the pension master trust and in the additional trusts for SoCalGas’ PBOP plans and SDG&E’s PBOP plan trusts are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PBOP PLANS (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 1 $ — $ 1 Equity securities – Domestic 1 — 1 Registered investment companies: Domestic 74 — 74 International 8 — 8 Fixed income securities: Domestic government and government agencies 8 — 8 Domestic corporate bonds — 5 5 International corporate bonds — 1 1 Derivative financial instruments (1) — (1) Total investment assets in the fair value hierarchy 91 6 97 Accounts receivable/payable, net 1 Investments measured at NAV: Common/collective trusts 21 Other 26 Total SDG&E investment assets 145 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PBOP PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Total SoCalGas: Cash and cash equivalents $ 2 $ — $ 2 Equity securities: Domestic 5 — 5 International 2 — 2 Registered investment companies – Domestic 87 103 190 Fixed income securities: Domestic government and government agencies 74 14 88 International government bonds — 10 10 Domestic corporate bonds — 295 295 International corporate bonds — 45 45 Derivative financial instruments 1 — 1 Total investment assets in the fair value hierarchy 171 467 638 Accounts receivable/payable, net 9 Investments measured at NAV – Common/collective trusts 361 Total SoCalGas investment assets 1,008 Other Sempra: Equity securities – International 1 — 1 Registered investment companies – Domestic 4 — 4 Fixed income securities: Domestic government and government agencies — 1 1 Domestic corporate bonds — 4 4 Total investment assets in the fair value hierarchy 5 5 10 Investments measured at NAV – Common/collective trusts 22 Total Other Sempra investment assets 32 Total Sempra investment assets in the fair value hierarchy $ 267 $ 478 Total Sempra investment assets $ 1,185 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PBOP PLANS (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 8 $ — $ 8 International 3 — 3 Registered investment companies: Domestic 71 — 71 International 7 — 7 Fixed income securities: Domestic government and government agencies 12 1 13 Domestic corporate bonds — 5 5 International corporate bonds — 1 1 Derivative financial instruments 2 — 2 Total investment assets in the fair value hierarchy 103 7 110 Accounts receivable/payable, net (2) Investments measured at NAV: Common/collective trusts 10 Other 32 Total SDG&E investment assets 150 SoCalGas: Cash and cash equivalents 7 — 7 Equity securities: Domestic 57 — 57 International 22 — 22 Registered investment companies – Domestic 78 103 181 Fixed income securities: Domestic government and government agencies 128 14 142 International government bonds — 9 9 Domestic corporate bonds — 295 295 International corporate bonds — 42 42 Derivative financial instruments (6) — (6) Total investment assets in the fair value hierarchy 286 463 749 Accounts receivable/payable, net 4 Investments measured at NAV: Common/collective trusts 233 Other 4 Total SoCalGas investment assets 990 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PBOP PLANS (CONTINUED) (Dollars in millions) Fair value at December 31, 2023 Level 1 Level 2 Total Other Sempra: Equity securities: Domestic $ 7 $ — $ 7 International 3 — 3 Registered investment companies – Domestic 3 — 3 Fixed income securities: Domestic government and government agencies 2 1 3 Domestic corporate bonds — 4 4 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 15 6 21 Investments measured at NAV: Common/collective trusts 7 Other 1 Total Other Sempra investment assets 29 Total Sempra investment assets in the fair value hierarchy $ 404 $ 476 Total Sempra investment assets $ 1,169
Schedule Of Defined Benefit Plans, Estimated Future Employer Contributions In Next Fiscal Year	We expect to contribute the following amounts to our pension and PBOP plans in 2025: EXPECTED CONTRIBUTIONS (Dollars in millions) Sempra SDG&E SoCalGas Pension plans $ 280 $ 54 $ 188 PBOP plans 3 1 1
Schedule of Expected Benefit Payments	The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets. EXPECTED BENEFIT PAYMENTS (Dollars in millions) Sempra SDG&E SoCalGas Pension PBOP Pension PBOP Pension PBOP 2025 $ 276 $ 48 $ 68 $ 11 $ 162 $ 35 2026 246 50 63 10 151 34 2027 258 46 62 10 146 34 2028 236 46 67 10 144 34 2029 230 46 61 10 143 34 2030-2034 1,161 229 305 47 721 171
Schedule Of Defined Benefit Plans Contributions	Employer contributions to the savings plans were as follows: EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra $ 65 $ 59 $ 64 SDG&E 22 20 19 SoCalGas 33 32 30

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 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) December 31, Commodity Unit of measure 2024 2023 Sempra: Natural gas MMBtu 637 361 Electricity MWh — 1 Congestion revenue rights MWh 27 36 SDG&E: Natural gas MMBtu 16 17 Congestion revenue rights MWh 27 36 SoCalGas: Natural gas MMBtu 347 268
Notional Amounts Of Interest Rate 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) December 31, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Cash flow hedges (1) $ 271 2025-2034 $ 4,451 2024-2048 Undesignated derivatives 3,189 2025-2048 — — (1) At December 31, 2024 and 2023, cash flow hedges accrued interest based on a notional amount of $271 and $488, respectively. 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) December 31, 2024 December 31, 2023 Notional amount Maturities Notional amount Maturities Sempra: Foreign currency derivatives $ 162 2025-2026 $ 176 2024-2025
Derivative Instruments on the Consolidated Balance Sheet Table	The following tables provide the fair values of derivative instruments on the Consolidated Balance Sheets, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions. We discuss the fair value of derivative assets and liabilities in Note 10. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 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 $ 7 $ 28 $ — $ — Foreign exchange instruments 4 1 — — Derivatives not designated as hedging instruments: Interest rate instruments 12 246 — — Commodity contracts not subject to rate recovery 16 23 (21) (43) Associated offsetting commodity contracts (15) (23) 15 23 Commodity contracts subject to rate recovery 7 4 (55) (10) Associated offsetting commodity contracts (5) (2) 5 2 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 26 277 (46) (24) Additional cash collateral for commodity contracts not subject to rate recovery 40 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (2) $ 91 $ 277 $ (46) $ (24) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ 4 $ (13) $ (6) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral — — 10 4 Net amounts presented on the balance sheet 2 2 (1) — Additional cash collateral for commodity contracts subject to rate recovery 21 — — — Total (2) $ 23 $ 2 $ (1) $ — SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (42) $ (4) Associated offsetting commodity contracts (3) — 3 — Net amounts presented on the balance sheet — — (39) (4) Additional cash collateral for commodity contracts subject to rate recovery 4 — — — Total $ 4 $ — $ (39) $ (4) (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 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 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 Consolidated Statements Of Operations Table	The following table includes the effects of derivative instruments designated as hedges on the Consolidated Statements of Operations and in OCI and AOCI. HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) Pretax gain (loss) reclassified Years ended December 31, Years ended December 31, 2024 2023 2022 Location 2024 2023 2022 Sempra: Cash flow hedges: Interest rate instruments $ 36 $ 45 $ 40 Interest expense $ 11 $ (1) $ (1) Interest rate instruments 21 20 205 Equity earnings (1) 23 48 (29) Foreign exchange instruments 14 (2) (8) Revenues: Energy- related businesses 5 (1) 1 Other income, net 2 (2) (1) Foreign exchange instruments 12 (3) (5) Equity earnings (1) 6 (2) — Interest rate and foreign exchange instruments — 7 25 Interest expense — 1 2 Other income, net — 6 12 Fair value hedges: Foreign exchange instruments 2 — — Equity earnings (1) — — — Total $ 85 $ 67 $ 257 $ 47 $ 49 $ (16) SoCalGas: Cash flow hedges: Interest rate instruments $ — $ — $ — Interest expense $ (1) $ (1) $ (1) (1) Equity earnings at Oncor Holdings and our foreign equity method investees are recognized after tax.
Undesignated Derivative Impact on the Consolidated Statements of Operations	The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2024 2023 2022 Sempra: Commodity contracts not subject to rate recovery Revenues: Energy-related businesses $ 223 $ 919 $ (1,116) Commodity contracts subject to rate recovery Cost of natural gas (56) (288) (56) Commodity contracts subject to rate recovery Cost of electric fuel and purchased power (41) 15 202 Interest rate instruments Interest expense 243 (47) 33 Total $ 369 $ 599 $ (937) SDG&E: Commodity contracts subject to rate recovery Cost of electric fuel and purchased power $ (41) $ 15 $ 202 SoCalGas: Commodity contracts subject to rate recovery Cost of natural gas $ (56) $ (288) $ (56)

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES (Dollars in millions) Fair value at December 31, 2024 Level 1 Level 2 Level 3 Netting (1) Total Sempra: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 8 $ 2 $ — $ 10 Equity securities 295 3 — 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 26 — 67 Municipal bonds — 287 — 287 Other securities — 228 — 228 Total debt securities 41 541 — 582 Total nuclear decommissioning trusts (2) 344 546 — 890 Short-term investments held in Rabbi Trust 64 — — 64 Support Agreement, net of related guarantee fees — — 25 25 Interest rate instruments — 293 — $ — 293 Foreign exchange instruments — 5 — — 5 Commodity contracts not subject to rate recovery — 39 — 2 41 Commodity contracts subject to rate recovery 6 1 4 18 29 Total $ 414 $ 884 $ 29 $ 20 $ 1,347 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ 63 $ — $ (38) $ 26 Commodity contracts subject to rate recovery 20 45 — (21) 44 Total $ 21 $ 108 $ — $ (59) $ 70 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 December 31, 2024 SDG&E: Assets: Nuclear decommissioning trusts: Short-term investments, primarily cash equivalents $ 8 $ 2 $ — $ 10 Equity securities 295 3 — 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 26 — 67 Municipal bonds — 287 — 287 Other securities — 228 — 228 Total debt securities 41 541 — 582 Total nuclear decommissioning trusts (2) 344 546 — 890 Commodity contracts subject to rate recovery 4 — 4 $ 17 25 Total $ 348 $ 546 $ 4 $ 17 $ 915 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 December 31, 2024 SoCalGas: Assets: Commodity contracts subject to rate recovery $ 2 $ 1 $ — $ 1 $ 4 Liabilities: Commodity contracts subject to rate recovery $ 2 $ 44 $ — $ (3) $ 43 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 Table	The table below sets forth reconciliations of changes in the fair value of CRRs and, until December 31, 2022, fixed-price electricity positions, classified as Level 3 in the fair value hierarchy for Sempra and SDG&E. LEVEL 3 RECONCILIATIONS (1) (Dollars in millions) 2024 2023 2022 Balance at January 1 $ 10 $ 35 $ 54 Realized and unrealized gains (losses), net (10) (17) (56) Allocated transmission instruments 3 (1) (4) Settlements 1 (7) 41 Balance at December 31 $ 4 $ 10 $ 35 Change in unrealized losses relating to instruments still held at December 31 $ (4) $ (13) $ (10) (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) 2024 2023 2022 Balance at January 1 $ 23 $ 17 $ 7 Realized and unrealized gains (losses), net (1) 11 15 19 Settlements (9) (9) (9) Balance at December 31 (2) $ 25 $ 23 $ 17 Change in unrealized gains relating to instruments still held at December 31 $ 8 $ 13 $ 18 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations. (2) Balance at December 31, 2024 and 2023 includes $7 in Other Current Assets, and $18 and $16, respectively, in Other Long-Term Assets on Sempra’s Consolidated Balance Sheet.
Schedule of Auction Price Inputs	For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below: CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2025 $ (7.38) to $ 15.54 $ 0.01 2024 (3.69) to 9.55 (0.44) 2023 (3.09) to 10.71 (0.56)
Fair Value of Financial Instruments Table	The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) Carrying Fair value amount Level 1 Level 2 Level 3 Total December 31, 2024 Sempra: Long-term note receivable (1) $ 351 $ — $ — $ 334 $ 334 Long-term amounts due to unconsolidated affiliates 352 — 324 — 324 Total long-term debt (2) 32,899 — 30,193 — 30,193 SDG&E: Total long-term debt (3) $ 8,950 $ — $ 7,760 $ — $ 7,760 SoCalGas: Total long-term debt (4) $ 7,359 $ — $ 6,880 $ — $ 6,880 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 December 31, 2024 and 2023, respectively. Excludes unamortized transaction costs of $3 and $4 at December 31, 2024 and 2023, respectively. (2) After the effects of interest rate swaps. Before reductions of unamortized discount and debt issuance costs of $382 and $322 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $1,315 and $1,340 at December 31, 2024 and 2023, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $95 and $89 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $1,205 and $1,233 at December 31, 2024 and 2023, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $65 and $55 at December 31, 2024 and 2023, respectively, and excluding finance lease obligations of $110 and $107 at December 31, 2024 and 2023, respectively.

PREFERRED STOCK (Tables)

PREFERRED STOCK (Tables)	12 Months Ended
	Dec. 31, 2024
Equity [Abstract]
Schedule Of Preferred Stock	The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2024 2023 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2) (2) Sempra - Total preferred stock of subsidiary $ 20 $ 20

SEMPRA - EQUITY AND EARNINGS _2

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE (Tables)	12 Months Ended
	Dec. 31, 2024
Earnings Per Share [Abstract]
Schedule Of Common Stock Activity	The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY 2024 2023 2022 Sempra: Common shares outstanding, January 1 631,431,732 628,669,356 633,839,564 Shares issued under forward sale agreements 17,142,858 — — Shares issued to underwriters to cover overallotments — 2,099,152 — RSUs vesting (1) 1,320,561 941,910 914,444 Stock options exercised 143,944 — 81,260 Common stock investment plan (2) 1,151,877 1,730 — Issuance of RSUs held in our Deferred Compensation Plan 128,207 132,178 130,026 Shares repurchased (3) (689,303) (412,594) (6,295,938) Common shares outstanding, December 31 650,629,876 631,431,732 628,669,356 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) Includes shares repurchased under repurchase programs and shares withheld from LTIP participants and individuals exercising stock options in 2024 to satisfy minimum statutory tax withholding requirements.
Schedule Of Noncontrolling 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) Years ended December 31, 2023 2022 Sempra: Net income attributable to Sempra $ 3,075 $ 2,139 Transfers (to) from NCI: (Decrease) increase in shareholders’ equity for sales of NCI (49) 710 Net transfers (to) from NCI (49) 710 Change from net income attributable to Sempra and transfers (to) from NCI $ 3,026 $ 2,849
Schedule Of Earnings Per Share Computations	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2024 2023 2022 Sempra: Numerator: Earnings attributable to common shares $ 2,817 $ 3,030 $ 2,094 Denominator: Weighted-average common shares outstanding for basic EPS (1) 633,795 630,296 630,318 Dilutive effect of stock options and RSUs (2) 2,112 2,341 2,439 Dilutive effect of common shares sold forward 2,036 96 — Weighted-average common shares outstanding for diluted EPS 637,943 632,733 632,757 EPS: Basic $ 4.44 $ 4.81 $ 3.32 Diluted $ 4.42 $ 4.79 $ 3.31 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 617 in 2024, 717 in 2023 and 805 in 2022. 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)

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Schedule Of Share-based Compensation Expense	Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra: Share-based compensation expense, before income taxes (1) $ 77 $ 71 $ 61 Income tax benefit (1) (9) (9) (17) $ 68 $ 62 $ 44 Capitalized share-based compensation cost $ 13 $ 12 $ 11 Excess income tax (benefit) deficiency (9) (6) (3) SDG&E: Share-based compensation expense, before income taxes $ 12 $ 13 $ 11 Income tax benefit (2) (2) (3) $ 10 $ 11 $ 8 Capitalized share-based compensation cost $ 7 $ 7 $ 6 Excess income tax (benefit) deficiency (1) (1) — SoCalGas: Share-based compensation expense, before income taxes $ 20 $ 18 $ 17 Income tax benefit (4) (3) (5) $ 16 $ 15 $ 12 Capitalized share-based compensation cost $ 6 $ 5 $ 5 Excess income tax (benefit) deficiency (2) (1) — (1) Includes activity of awards issued from the IEnova 2013 LTIP, which settled in cash upon vesting based on the price of IEnova’s common stock.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	To calculate this fair value, we used the Black-Scholes model with the following weighted-average assumptions: KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Years ended December 31, 2024 2023 2022 Sempra: Stock price volatility 26.49 % 27.35 % 26.08 % Expected term 5.36 years 5.36 years 5.36 years Risk-free rate of return 3.90 % 3.89 % 1.40 % Annual dividend yield 3.14 % 2.98 % 3.33 %
Schedule Of Non-qualified Stock Options	The following table shows a summary of nonqualified stock options at December 31, 2024 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value Sempra: Outstanding at January 1, 2024 1,759,798 $ 65.99 Granted 414,812 $ 75.82 Exercised (23,713) $ 62.87 Withheld related to net settlement (120,231) $ 62.87 Outstanding at December 31, 2024 2,030,666 $ 68.22 6.78 $ 40 Vested or expected to vest at December 31, 2024 2,030,666 $ 68.22 6.78 $ 40 Exercisable at December 31, 2024 1,251,544 $ 64.45 5.81 $ 29
Schedule Of Restricted Stock Awards And Units Valuation Assumptions	Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2024 2023 2022 Sempra: Stock price volatility 21.27 % 35.31 % 32.82 % Risk-free rate of return 4.06 % 4.13 % 1.05 %
Schedule Of Restricted Stock Units	The following table shows a summary of RSUs at December 31, 2024 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based Service-based Units Weighted- average Units Weighted- average grant-date fair value Sempra: Nonvested at January 1, 2024 1,829,984 $ 74.46 524,969 $ 70.63 Granted 721,049 $ 75.70 321,576 $ 75.86 Vested (571,322) $ 66.52 (281,494) $ 68.68 Forfeited (73,987) $ 76.78 (21,963) $ 88.74 Nonvested at December 31, 2024 (1) 1,905,724 $ 77.22 543,088 $ 74.55 Expected to vest at December 31, 2024 1,865,938 $ 77.19 525,029 $ 74.49 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra exceeds target performance conditions.

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	12 Months Ended
	Dec. 31, 2024
Regulated Operations [Abstract]
Schedule of Nuclear Decommissioning Trusts	The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 10. NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross Gross Estimated December 31, 2024 Short-term investments, primarily cash equivalents $ 10 $ — $ — $ 10 Equity securities 78 223 (3) 298 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) 67 1 (1) 67 Municipal bonds (2) 295 1 (9) 287 Other securities (3) 234 2 (8) 228 Total debt securities 596 4 (18) 582 Receivables (payables), net (15) — — (15) Total $ 669 $ 227 $ (21) $ 875 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 2025-2062. (3) Maturity dates are 2025-2072.
Schedule of Securities Sold	The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Proceeds from sales $ 874 $ 592 $ 639 Gross realized gains 57 27 18 Gross realized losses 10 14 20

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Schedule of Leases Statement of Financial Position	Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below. LESSEE INFORMATION ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) Sempra SDG&E SoCalGas December 31, 2024 2023 2024 2023 2024 2023 ROU assets: Operating leases: ROU assets $ 1,177 $ 723 $ 795 $ 368 $ 18 $ 29 Finance leases: PP&E 1,626 1,585 1,426 1,412 200 173 Accumulated depreciation (311) (246) (221) (179) (90) (66) PP&E, net 1,315 1,339 1,205 1,233 110 107 Total ROU assets $ 2,492 $ 2,062 $ 2,000 $ 1,601 $ 128 $ 136 Lease liabilities: Operating leases: Other current liabilities (1) $ 91 $ 70 $ 68 $ 50 $ 8 $ 10 Deferred credits and other (2) 1,019 599 734 325 9 18 1,110 669 802 375 17 28 Finance leases: Current portion of long-term debt and finance leases 65 64 42 41 23 23 Long-term debt and finance leases 1,250 1,276 1,163 1,192 87 84 1,315 1,340 1,205 1,233 110 107 Total lease liabilities $ 2,425 $ 2,009 $ 2,007 $ 1,608 $ 127 $ 135 Weighted-average remaining lease term (in years): Operating leases 13 13 12 10 2 3 Finance leases 14 15 15 16 6 6 Weighted-average discount rate: Operating leases (3) 6.10 % 6.64 % 5.06 % 4.52 % 4.70 % 4.54 % Finance leases 13.71 % 13.80 % 14.11 % 14.18 % 5.35 % 4.94 % (1) Includes $43 and $18 related to PPAs at December 31, 2024 and 2023, respectively, at both Sempra and SDG&E. (2) Includes $627 and $208 related to PPAs at December 31, 2024 and 2023, respectively, at both Sempra and SDG&E. (3) Weighted-average discount rate related to PPAs at December 31, 2024 and 2023 is 5.04% and 4.19%, respectively, at both Sempra and SDG&E. Weighted-average discount rate related to all other operating leases at December 31, 2024 and 2023 is 7.41% and 7.57%, respectively, at Sempra and 5.23% and 5.06%, respectively, at SDG&E.
Lease, Cost	The components of lease costs were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 2024 2023 2022 Operating lease costs (2) $ 118 $ 99 $ 83 $ 71 $ 53 $ 45 $ 12 $ 13 $ 18 Finance lease costs: Amortization of ROU assets (3) 65 60 48 42 40 33 23 20 15 Interest on lease liabilities 178 182 184 173 177 181 6 5 2 Total finance lease costs 243 242 232 215 217 214 29 25 17 Short-term lease costs (4) 9 9 3 8 8 2 — — — Variable lease costs (4) 472 458 411 460 447 399 10 10 11 Total lease costs $ 842 $ 808 $ 729 $ 754 $ 725 $ 660 $ 51 $ 48 $ 46 (1) Includes costs capitalized in PP&E. (2) Includes $37, $21, and $10 related to PPAs in 2024, 2023 and 2022, respectively, at both Sempra and SDG&E. (3) Included in O&M, except for $30, $29 and $25 at Sempra and $29, $28 and $24 at SDG&E in 2024, 2023 and 2022, respectively, and $1 at SoCalGas in each of 2024, 2023 and 2022, which is included in Depreciation and Amortization Expense. (4) Short-term leases with variable lease costs are recorded and presented as variable lease costs.
Schedule of Cash Flow, Supplemental Disclosures	Cash paid for amounts included in the measurement of lease liabilities and supplemental noncash information were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Dollars in millions) Sempra SDG&E SoCalGas Years ended December 31, 2024 2023 2022 2024 2023 2022 2024 2023 2022 Operating activities: Cash paid for operating leases $ 112 $ 85 $ 88 $ 70 $ 46 $ 45 $ 12 $ 13 $ 18 Cash paid for finance leases 163 167 169 158 162 166 6 5 2 Financing activities: Cash paid for finance leases 66 60 48 42 40 33 24 20 15 Increase in operating lease obligations for ROU assets 520 143 142 474 134 134 — — 1 Increase in finance lease obligations for investment in PP&E 41 57 57 14 17 16 27 40 41
Lessee, Operating Lease, Liability, Maturity	The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities at December 31, 2024: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) Sempra SDG&E SoCalGas Operating leases (1) Finance leases Operating leases (1) Finance leases (2) Operating leases Finance leases 2025 $ 142 $ 224 $ 97 $ 196 $ 10 $ 28 2026 142 220 98 195 7 25 2027 134 218 97 194 — 24 2028 128 212 92 193 — 19 2029 124 204 89 190 — 14 Thereafter 966 1,745 571 1,727 — 18 Total undiscounted lease payments 1,636 2,823 1,044 2,695 17 128 Less: imputed interest (526) (1,508) (242) (1,490) — (18) Total lease liabilities 1,110 1,315 802 1,205 17 110 Less: current lease liabilities (91) (65) (68) (42) (8) (23) Long-term lease liabilities $ 1,019 $ 1,250 $ 734 $ 1,163 $ 9 $ 87 (1) Includes $76 in 2025, $75 in 2026, $76 in 2027, $75 in each of 2028 and 2029, and $525 thereafter related to PPAs. (2) Substantially all amounts are related to PPAs.
Finance Lease, Liability, Maturity	The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities at December 31, 2024: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) Sempra SDG&E SoCalGas Operating leases (1) Finance leases Operating leases (1) Finance leases (2) Operating leases Finance leases 2025 $ 142 $ 224 $ 97 $ 196 $ 10 $ 28 2026 142 220 98 195 7 25 2027 134 218 97 194 — 24 2028 128 212 92 193 — 19 2029 124 204 89 190 — 14 Thereafter 966 1,745 571 1,727 — 18 Total undiscounted lease payments 1,636 2,823 1,044 2,695 17 128 Less: imputed interest (526) (1,508) (242) (1,490) — (18) Total lease liabilities 1,110 1,315 802 1,205 17 110 Less: current lease liabilities (91) (65) (68) (42) (8) (23) Long-term lease liabilities $ 1,019 $ 1,250 $ 734 $ 1,163 $ 9 $ 87 (1) Includes $76 in 2025, $75 in 2026, $76 in 2027, $75 in each of 2028 and 2029, and $525 thereafter related to PPAs. (2) Substantially all amounts are related to PPAs.
Lessor, Operating Lease, Payments to be Received, Maturity	LESSOR INFORMATION (Dollars in millions) December 31, 2024 2023 Sempra – Assets subject to operating leases: Property, plant and equipment: Pipelines and storage $ 1,313 $ 1,304 Refined products terminals 623 621 Other 77 77 Total 2,013 2,002 Accumulated depreciation (605) (539) Property, plant and equipment, net $ 1,408 $ 1,463 December 31, 2024 Sempra – Maturity analysis of lease payments: Operating leases Sales-type leases 2025 $ 318 $ 17 2026 272 9 2027 269 — 2028 268 — 2029 246 — Thereafter 2,324 — Total undiscounted cash flows $ 3,697 26 Less: present value of lease payments (recognized as lease receivable) (1) (23) Difference between undiscounted cash flows and discounted cash flows $ 3 (1) Includes $15 in Other Current Assets and $8 in Other Long-Term Assets on the Consolidated Balance Sheet.
Sales-type and Direct Financing Leases, Lease Receivable, Maturity	LESSOR INFORMATION (Dollars in millions) December 31, 2024 2023 Sempra – Assets subject to operating leases: Property, plant and equipment: Pipelines and storage $ 1,313 $ 1,304 Refined products terminals 623 621 Other 77 77 Total 2,013 2,002 Accumulated depreciation (605) (539) Property, plant and equipment, net $ 1,408 $ 1,463 December 31, 2024 Sempra – Maturity analysis of lease payments: Operating leases Sales-type leases 2025 $ 318 $ 17 2026 272 9 2027 269 — 2028 268 — 2029 246 — Thereafter 2,324 — Total undiscounted cash flows $ 3,697 26 Less: present value of lease payments (recognized as lease receivable) (1) (23) Difference between undiscounted cash flows and discounted cash flows $ 3 (1) Includes $15 in Other Current Assets and $8 in Other Long-Term Assets on the Consolidated Balance Sheet.
Operating Lease, Lease Income	LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra – Sales-type leases: Interest income $ 5 $ 6 $ 8 Total revenues from sales-type leases (1) $ 5 $ 6 $ 8 Sempra – Operating leases: Fixed lease payments $ 340 $ 321 $ 290 Variable lease payments 38 34 10 Total revenues from operating leases (1) $ 378 $ 355 $ 300 Depreciation expense $ 73 $ 62 $ 54 (1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.
Sales-type Lease, Lease Income	LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra – Sales-type leases: Interest income $ 5 $ 6 $ 8 Total revenues from sales-type leases (1) $ 5 $ 6 $ 8 Sempra – Operating leases: Fixed lease payments $ 340 $ 321 $ 290 Variable lease payments 38 34 10 Total revenues from operating leases (1) $ 378 $ 355 $ 300 Depreciation expense $ 73 $ 62 $ 54 (1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.
Schedule Of Estimated Future Payments Under Natural Gas Contracts	At December 31, 2024, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts are as follows: FUTURE MINIMUM PAYMENTS (Dollars in millions) Sempra SoCalGas Storage and Natural gas (1) Total (1) Transportation Natural gas Total 2025 $ 229 $ 65 $ 294 $ 130 $ 61 $ 191 2026 225 175 400 125 108 233 2027 203 271 474 104 124 228 2028 155 242 397 71 83 154 2029 140 152 292 59 — 59 Thereafter 1,283 212 1,495 118 — 118 Total minimum payments $ 2,235 $ 1,117 $ 3,352 $ 607 $ 376 $ 983 (1) Excludes amounts related to the LNG purchase agreement that we discuss below.
Schedule Of Payments Under Natural Gas Contracts	Total payments under natural gas contracts and natural gas storage and transportation contracts as well as payments to meet additional portfolio needs at Sempra and SoCalGas were as follows: PAYMENTS UNDER NATURAL GAS CONTRACTS (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra $ 1,185 $ 4,030 $ 2,536 SoCalGas 1,088 3,857 2,492
Schedule Of LNG Commitment Amounts	At December 31, 2024, the following 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 December 31, 2024. LNG COMMITMENT AMOUNTS (Dollars in millions) Sempra: 2025 $ 355 2026 640 2027 657 2028 646 2029 402 Total $ 2,700
Schedule Of Estimated Future Payments Under Purchased Power Contracts	At December 31, 2024, the future minimum payments under long-term PPAs for Sempra and SDG&E are as follows: FUTURE MINIMUM PAYMENTS (1) (Dollars in millions) 2025 $ 97 2026 116 2027 114 2028 114 2029 114 Thereafter 746 Total minimum payments $ 1,301 (1) Excludes PPAs accounted for as operating leases and finance leases.
Schedule Of Environmental Remediation Costs Capitalized In Period	The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: CAPITAL EXPENDITURES FOR ENVIRONMENTAL ISSUES (Dollars in millions) Years ended December 31, 2024 2023 2022 Sempra $ 65 $ 107 $ 87 SDG&E 23 29 31 SoCalGas 42 78 56
Schedule Of Environmental Remediation Costs, Status Of Remediation Sites	The table below shows the status at December 31, 2024 of SDG&E’s and SoCalGas’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP: STATUS OF ENVIRONMENTAL SITES # Sites complete (1) # Sites SDG&E: Manufactured-gas sites 3 — Third-party waste-disposal sites 2 1 SoCalGas: Manufactured-gas sites 39 3 Third-party waste-disposal sites 5 2 (1) There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
Schedule of Environmental Loss Contingencies by Site	The following table shows our accrued liabilities for environmental matters at December 31, 2024. Of the total liability, $14 million at SoCalGas is recorded on a discounted basis, with a weighted-average discount rate of 2.45%. ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS (Dollars in millions) Sempra (1) SDG&E (1) SoCalGas Manufactured-gas sites $ 34 $ — $ 34 Waste disposal sites (PRP) (2) 8 5 3 Other hazardous waste sites 12 11 1 Total (3) $ 54 $ 16 $ 38 (1) Does not include SDG&E’s liability for SONGS marine environment mitigation. (2) Sites for which we have been identified as a PRP. (3) noncurrent liabilities

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables present selected information by segment and reconciliations of assets, capital expenditures for PP&E, and earnings attributable to common shares to Sempra’s consolidated totals. SEGMENT INFORMATION (Dollars in millions) December 31, 2024 2023 ASSETS Sempra California $ 56,116 $ 53,430 Sempra Texas Utilities 15,534 14,392 Sempra Infrastructure 22,954 19,430 Segment totals 94,604 87,252 Parent and other 2,622 967 Intersegment eliminations (1) (1,071) (1,038) Total Sempra $ 96,155 $ 87,181 EQUITY METHOD INVESTMENTS Sempra Texas Utilities $ 15,522 $ 14,380 Sempra Infrastructure 2,411 2,129 Segment totals/Total Sempra $ 17,933 $ 16,509 GEOGRAPHIC LOCATION OF PROPERTY, PLANT AND EQUIPMENT, NET United States $ 52,952 $ 46,935 Mexico 8,485 8,024 Rest of the world — 1 Total Sempra $ 61,437 $ 54,960 Years ended December 31, 2024 2023 2022 CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT Sempra California $ 4,753 $ 4,560 $ 4,466 Sempra Infrastructure 3,459 3,832 884 Segment totals 8,212 8,392 5,350 Parent and other 3 5 7 Total Sempra $ 8,215 $ 8,397 $ 5,357 GEOGRAPHIC LOCATION OF REVENUES (2) United States $ 11,623 $ 14,973 $ 13,015 Mexico 1,562 1,747 1,424 Total Sempra $ 13,185 $ 16,720 $ 14,439 (1) Primarily includes an intersegment loan from Sempra Infrastructure to Parent and other related to deferred income taxes. (2) Amounts are based on where the revenue originated, after intersegment eliminations. SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Sempra California Sempra Texas Utilities (1) Sempra Infrastructure Sempra Year ended December 31, 2024 Revenues $ 11,382 $ 1,882 Depreciation and amortization (2,133) (297) Interest income 14 25 Interest expense (2) (848) 243 Income tax (expense) benefit (184) 164 Equity earnings — $ 788 802 Earnings attributable to noncontrolling interests — — (638) Other segment items (3) (6,385) (7) (1,270) Segment earnings attributable to common shares $ 1,846 $ 781 $ 911 $ 3,538 Parent and other (721) Earnings attributable to common shares $ 2,817 Year ended December 31, 2023 Revenues $ 13,761 $ 3,071 Depreciation and amortization (1,937) (281) Interest income 24 43 Interest expense (2) (782) (129) Income tax benefit (expense) 31 (673) Equity earnings — $ 701 740 Earnings attributable to noncontrolling interests — — (543) Other segment items (3) (9,350) (7) (1,351) Segment earnings attributable to common shares $ 1,747 $ 694 $ 877 $ 3,318 Parent and other (288) Earnings attributable to common shares $ 3,030 Year ended December 31, 2022 Revenues $ 12,577 $ 1,919 Depreciation and amortization (1,743) (268) Interest income 11 44 Interest expense (647) (104) Income tax expense (320) (249) Equity earnings — $ 742 756 Earnings attributable to noncontrolling interests — — (146) Other segment items (3) (8,364) (6) (1,642) Segment earnings attributable to common shares $ 1,514 $ 736 $ 310 $ 2,560 Parent and other (466) Earnings attributable to common shares $ 2,094 (1) Substantially all earnings attributable to common shares are from equity earnings. (2) Sempra Infrastructure includes net unrealized gains (losses) from undesignated interest rate swaps related to the PA LNG Phase 1 project. (3) Includes cost of natural gas, cost of electric fuel and purchased power, O&M, Aliso Canyon litigation and regulatory matters, franchise fees and other taxes, other income (expense), net, and preferred dividends for Sempra California; O&M, interest expense, and income tax expense (benefit) for Sempra Texas Utilities related to activities at the holding company; and cost of natural gas, energy-related businesses cost of sales, O&M, franchise fees and other taxes, and other income (expense), net, for Sempra Infrastructure. The following table presents revenues by services by segment, reconciled to Sempra’s consolidated revenues. REVENUES BY SERVICES (Dollars in millions) Sempra California Sempra Infrastructure Sempra Year ended December 31, 2024 Revenues from external customers: Utilities $ 10,985 $ 78 Energy-related businesses — 755 Total revenues from external customers (1) 10,985 833 $ 11,818 Other revenues (2) : Utilities 374 — Energy-related businesses — 993 Total other revenues 374 993 1,367 Intersegment revenues (3) : Utilities 23 — Energy-related businesses — 56 Total intersegment revenues 23 56 79 Segment revenues $ 11,382 $ 1,882 13,264 Intersegment eliminations (79) Revenues $ 13,185 Year ended December 31, 2023 Revenues from external customers: Utilities $ 13,668 $ 87 Energy-related businesses — 1,094 Total revenues from external customers (1) 13,668 1,181 $ 14,849 Other revenues (2) : Utilities 75 — Energy-related businesses — 1,796 Total other revenues 75 1,796 1,871 Intersegment revenues (3) : Utilities 18 — Energy-related businesses — 94 Total intersegment revenues 18 94 112 Segment revenues $ 13,761 $ 3,071 16,832 Intersegment eliminations (112) Revenues $ 16,720 Year ended December 31, 2022 Revenues from external customers: Utilities $ 11,930 $ 89 Energy-related businesses — 1,704 Total revenues from external customers (1) 11,930 1,793 $ 13,723 Other revenues (2) : Utilities 633 — Energy-related businesses — 83 Total other revenues 633 83 716 Intersegment revenues (3) : Utilities 14 — Energy-related businesses — 43 Total intersegment revenues 14 43 57 Segment revenues $ 12,577 $ 1,919 14,496 Intersegment eliminations (57) Revenues $ 14,439 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of Sempra’s total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) See “Transactions with Affiliates” in Note 1 for a description of services provided by one operating segment to another operating segment within Sempra. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2024 2023 2022 SDG&E: Revenues from external customers: Electric $ 4,164 $ 4,750 $ 4,687 Natural gas 878 1,204 899 Total revenues from external customers (1) 5,042 5,954 5,586 Other revenues (2) : Electric 149 (401) 109 Natural gas 150 44 143 Total other revenues 299 (357) 252 Total revenues 5,341 5,597 5,838 Depreciation and amortization (1,223) (1,098) (982) Interest income 5 15 5 Interest expense (525) (497) (449) Income tax (expense) benefit (153) 26 (182) Other segment items (3) (2,554) (3,107) (3,315) Earnings attributable to common shares $ 891 $ 936 $ 915 Capital expenditures for property, plant and equipment $ 2,522 $ 2,540 $ 2,473 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of SDG&E’s total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) Includes cost of electric fuel and purchased power, cost of natural gas, O&M, franchise fees and other taxes, and other income (expense), net. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2024 2023 2022 SoCalGas: Natural gas: Revenues from external customers (1) $ 6,134 $ 7,857 $ 6,459 Other revenues (2) 75 432 381 Total revenues 6,209 8,289 6,840 Aliso Canyon litigation and regulatory matters — — (259) Depreciation and amortization (910) (839) (761) Interest income 9 9 6 Interest expense (323) (285) (198) Income tax (expense) benefit (31) 5 (138) Other segment items (3) (3,999) (6,368) (4,891) Earnings attributable to common shares $ 955 $ 811 $ 599 Capital expenditures for property, plant and equipment $ 2,231 $ 2,020 $ 1,993 (1) We did not have revenues from transactions with a single external customer that amounted to 10% or more of SoCalGas’ total revenues. (2) See “Revenues from Sources Other Than Contracts with Customers” in Note 3 for a description of this revenue source, which may be additive or subtractive from period to period. (3) Includes cost of natural gas, O&M, franchise fees and other taxes, and other income (expense), net, and preferred dividends.

SCHEDULE I - CONDENSED FINANC_2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
Schedule of Condensed Statements of Operations	SEMPRA CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2024 2023 2022 Interest income $ 29 $ 31 $ 35 Interest expense (490) (444) (326) Operating expenses (105) (101) (92) Other income (expense), net 25 31 (58) Income tax benefit 165 134 111 Loss before equity in earnings of subsidiaries (376) (349) (330) Equity in earnings of subsidiaries, net of income taxes 3,237 3,423 2,468 Net income 2,861 3,074 2,138 Preferred dividends (44) (44) (44) Earnings $ 2,817 $ 3,030 $ 2,094 Basic EPS: Earnings $ 4.44 $ 4.81 $ 3.32 Weighted-average common shares outstanding 633,795 630,296 630,318 Diluted EPS: Earnings $ 4.42 $ 4.79 $ 3.31 Weighted-average common shares outstanding 637,943 632,733 632,757 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Statements Of Comprehensive Income	SEMPRA CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2024, 2023 and 2022 Pretax Income tax benefit (expense) Net-of-tax 2024: Net income $ 2,696 $ 165 $ 2,861 Other comprehensive income (loss): Foreign currency translation adjustments (30) — (30) Financial instruments 14 (2) 12 Pension and other postretirement benefits 18 (16) 2 Total other comprehensive income (loss) 2 (18) (16) Comprehensive income $ 2,698 $ 147 $ 2,845 2023: Net income $ 2,940 $ 134 $ 3,074 Other comprehensive income (loss): Foreign currency translation adjustments 23 — 23 Financial instruments 57 (18) 39 Pension and other postretirement benefits (39) 8 (31) Total other comprehensive income 41 (10) 31 Comprehensive income $ 2,981 $ 124 $ 3,105 2022: Net income $ 2,027 $ 111 $ 2,138 Other comprehensive income (loss): Foreign currency translation adjustments 11 — 11 Financial instruments 221 (55) 166 Pension and other postretirement benefits 3 (6) (3) Total other comprehensive income 235 (61) 174 Comprehensive income $ 2,262 $ 50 $ 2,312 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Balance Sheets	SEMPRA CONDENSED BALANCE SHEETS (Dollars in millions) December 31, 2024 2023 Assets: Cash and cash equivalents $ 1,416 $ 3 Restricted cash 2 2 Due from affiliates 88 105 Income taxes receivable, net 71 — Other current assets 10 11 Total current assets 1,587 121 Investments in subsidiaries 42,305 38,499 Due from affiliates 25 18 Deferred income taxes 209 429 Other long-term assets 1,152 1,095 Total assets $ 45,278 $ 40,162 Liabilities and shareholders’ equity: Short-term debt $ — $ 365 Due to affiliates 241 235 Other current liabilities 1,410 819 Total current liabilities 1,651 1,419 Long-term debt 11,028 8,461 Due to affiliates 739 988 Other long-term liabilities 638 619 Commitments and contingencies (Note 4) Shareholders’ equity 31,222 28,675 Total liabilities and shareholders’ equity $ 45,278 $ 40,162 See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Statements of Cash Flows	SEMPRA CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2024 2023 2022 Net cash provided by operating activities $ 120 $ 1,576 $ 775 Expenditures for property, plant and equipment (3) (5) (7) Proceeds from sale of assets — 2 — Capital contributions to investees (933) (1,749) (661) Distributions from investments 9 108 — Purchases of trust assets (63) (78) (114) Proceeds from sales of trust assets 68 69 123 Increase in loans to affiliates, net (117) (90) (92) Premiums on corporate-owned life insurance policies (1) (1) (3) Net cash used in investing activities (1,040) (1,744) (754) Common dividends paid (1,499) (1,483) (1,430) Preferred dividends paid (44) (44) (44) Issuances of common stock, net 1,219 145 4 Repurchases of common stock (43) (32) (478) Issuances of debt (maturities greater than 90 days) 3,695 1,918 1,569 Payments on debt (maturities greater than 90 days) (350) (672) (322) Decrease in short-term debt, net (365) (89) (785) (Decrease) increase in loans from affiliates, net (241) 220 (226) Proceeds from sales of noncontrolling interests, net — — 1,732 Other (38) (10) (8) Net cash provided by (used in) financing activities 2,334 (47) 12 Effect of exchange rate changes on cash, cash equivalents and restricted cash (1) — (1) Increase (decrease) in cash, cash equivalents and restricted cash 1,413 (215) 32 Cash, cash equivalents and restricted cash, January 1 5 220 188 Cash, cash equivalents and restricted cash, December 31 $ 1,418 $ 5 $ 220 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Accrued interest receivable capitalized to note receivable $ 17 $ 16 $ 18 Preferred dividends declared but not paid 11 11 11 Common dividends declared but not paid 393 376 360 Common dividends issued in stock 54 — — Net exercise of stock options 9 — — Equitization of amounts due from affiliates 110 92 93 See Notes to Condensed Financial Information of Parent.
Schedule of Long-term Debt	The following tables show the detail and maturities of long-term debt outstanding. LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2024 2023 SDG&E: First mortgage bonds (collateralized by plant assets): 2.50% May 15, 2026 $ 500 $ 500 6.00% June 1, 2026 250 250 4.95% August 15, 2028 600 600 1.70% October 1, 2030 800 800 3.00% March 15, 2032 500 500 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 6.00% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.50% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.30% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.10% June 15, 2049 400 400 3.32% April 15, 2050 400 400 2.95% August 15, 2051 750 750 3.70% March 15, 2052 500 500 5.35% April 1, 2053 800 800 5.55% April 15, 2054 600 — 8,950 8,350 Other long-term debt (uncollateralized): Notes at variable rates (5.99% at December 31, 2023) February 18, 2024 (1) — 400 Finance lease obligations: Power purchase agreements 1,138 1,166 Other 67 67 1,205 1,633 10,155 9,983 Current portion of long-term debt and finance leases (42) (441) Unamortized discount on long-term debt (33) (29) Unamortized debt issuance costs (62) (60) Total SDG&E $ 10,018 $ 9,453 (1) Callable long-term debt not subject to make-whole provisions. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 $ — $ 500 3.20% June 15, 2025 350 350 2.60% June 15, 2026 500 500 2.55% February 1, 2030 650 650 5.20% June 1, 2033 500 500 5.05% September 1, 2034 600 — 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.30% January 15, 2049 550 550 3.95% February 15, 2050 350 350 6.35% November 15, 2052 600 600 5.75% June 1, 2053 500 500 5.60% April 1, 2054 500 — 6,650 6,050 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 2.95% Notes April 15, 2027 700 700 5.67% Notes January 18, 2028 (2) 5 5 Finance lease obligations 110 107 819 816 7,469 6,866 Current portion of long-term debt and finance leases (373) (523) Unamortized discount on long-term debt (18) (13) Unamortized debt issuance costs (47) (42) Total SoCalGas $ 7,031 $ 6,288 (1) Callable long-term debt not subject to make-whole provisions. (2) Debt is not callable. LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2024 2023 Other Sempra: Sempra - Other long-term debt (uncollateralized): 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Sempra Infrastructure - Other long-term debt (uncollateralized unless otherwise noted): Loan at variable rates (weighted-average rate of 7.29% and 8.31% at December 31, 2024 and 2023, respectively) December 9, 2025 1,063 832 3.75% Notes January 14, 2028 300 300 Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets (1) 1,090 258 3.25% Notes January 15, 2032 400 400 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034 (1) 90 96 Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable June 15, 2022 through November 19, 2034 (1) 90 96 2.90% Loan payable June 15, 2022 through November 19, 2034 (1) 219 231 4.875% Notes January 14, 2048 540 540 4.75% Notes January 15, 2051 800 800 4,682 3,649 16,590 12,207 Current portion of long-term debt (1,859) (11) Unamortized discount on long-term debt (78) (66) Unamortized debt issuance costs (144) (112) Total Other Sempra 14,509 12,018 Total Sempra $ 31,558 $ 27,759 (1) Callable long-term debt not subject to make-whole provisions. The following table shows the detail and maturities of uncollateralized long-term debt outstanding. LONG-TERM DEBT (Dollars in millions) December 31, 2024 2023 3.30% Notes April 1, 2025 $ 750 $ 750 5.40% Notes August 1, 2026 550 550 3.25% Notes June 15, 2027 750 750 3.40% Notes February 1, 2028 1,000 1,000 3.70% Notes April 1, 2029 500 500 5.50% Notes August 1, 2033 700 700 3.80% Notes February 1, 2038 1,000 1,000 6.00% Notes October 15, 2039 750 750 4.00% Notes February 1, 2048 800 800 4.125% (next rate reset on April 1, 2027) Junior Subordinated Notes April 1, 2052 (1) 1,000 1,000 6.40% (next rate reset on October 1, 2034) Junior Subordinated Notes October 1, 2054 (1) 1,250 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 600 — 6.875% (next rate reset on October 1, 2029) Junior Subordinated Notes October 1, 2054 (1) 500 — 6.55% (next rate reset on April 1, 2035) Junior Subordinated Notes April 1, 2055 (1) 600 — 6.625% (next rate reset on April 1, 2030) Junior Subordinated Notes April 1, 2055 (1) 400 — 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 758 11,908 8,558 Current portion of long-term debt (750) — Unamortized discount on long-term debt (30) (29) Unamortized debt issuance costs (100) (68) Total long-term debt $ 11,028 $ 8,461 (1) Callable long-term debt not subject to make-whole provisions.

SIGNIFICANT ACCOUNTING POLICI_4

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	12 Months Ended
	Dec. 31, 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

SIGNIFICANT ACCOUNTING POLICI_5

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - REGULATED OPERATIONS (Details) - Sempra Texas Utilities	Dec. 31, 2024
Oncor Electric Delivery Company LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	80.25%
Sharyland Utilities, LP | Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	100%

SIGNIFICANT ACCOUNTING POLICI_6

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Jul. 31, 2020 project_owner
Variable Interest Entity [Line Items]
Property, plant and equipment, net	$ 61,437	$ 54,960
Total finance leases	1,315	1,340
Equity method investment	15,400	14,266
Assets	96,155	87,181
SDG&E
Variable Interest Entity [Line Items]
Property, plant and equipment, net	25,111	23,549
Total finance leases	1,205	1,233
Assets	30,773	29,185
SDG&E | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Property, plant and equipment, net	1,138	1,166
Total finance leases	1,138	1,166
Cameron LNG
Variable Interest Entity [Line Items]
Number of project owners | project_owner			4
Sempra Infrastructure | Variable Interest Entity, Primary Beneficiary | Port Arthur LNG
Variable Interest Entity [Line Items]
Assets	6,419	3,927
Liabilities	1,584	600
Sempra Infrastructure | Variable Interest Entity, Primary Beneficiary | ECA LNG JV
Variable Interest Entity [Line Items]
Assets	1,758	1,580
Liabilities	1,080	1,029
Sempra Infrastructure | Cameron LNG JV
Variable Interest Entity [Line Items]
Equity method investment	1,149	1,008
Oncor Holdings | Sempra Texas Utilities
Variable Interest Entity [Line Items]
Equity method investment	$ 15,400	$ 14,266
ECA LNG JV | IEnova
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity	83.40%
ECA LNG JV | Subsidiary of TOTAL SE
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity	16.60%

SIGNIFICANT ACCOUNTING POLICI_7

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 1,565	$ 236
Restricted cash, current	21	49
Restricted cash, noncurrent	3	104
Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows	$ 1,589	$ 389

SIGNIFICANT ACCOUNTING POLICI_8

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 533	$ 181	$ 136
Provisions for expected credit losses	203	468	123
Write-offs	(222)	(116)	(78)
Ending balance	514	533	181
Accounts receivable - trade and other, net	53	52
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	447	480
Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	53	52
Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	14	1
Other long-term assets | KKR
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 loss related to guarantees	5	5
SDG&E
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	144	78	66
Provisions for expected credit losses	52	115	54
Write-offs	(82)	(49)	(42)
Ending balance	114	144	78
SDG&E | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	81	116
SDG&E | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	25	27
SDG&E | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	8	1
SoCalGas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	331	98	69
Provisions for expected credit losses	94	300	65
Write-offs	(140)	(67)	(36)
Ending balance	285	331	$ 98
SoCalGas | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	251	306
SoCalGas | Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	28	25
SoCalGas | Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	$ 6	$ 0

SIGNIFICANT ACCOUNTING POLICI_9

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	$ 13	$ 31
Due to unconsolidated affiliates, noncurrent	(352)	(307)
Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	13	31
Total due to unconsolidated affiliates – current	0	(5)
Due to unconsolidated affiliates, noncurrent	(352)	(307)
Other related parties
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	5	6
Tax Sharing Arrangement | Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	8	25
SDG&E | Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(59)	(73)
SDG&E | Other related parties
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(3)	(8)
SDG&E | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(42)	(44)
SDG&E | Due to/from SoCalGas
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(14)	(21)
SoCalGas
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	16	22
SoCalGas | Related Party
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	16	22
Total due to unconsolidated affiliates – current	(38)	(38)
SoCalGas | Other related parties
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	2	1
SoCalGas | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(38)	(38)
Income taxes due from (to) Sempra	(6)	6
SoCalGas | Due to/from SDGE
Related Party Transaction [Line Items]
Due from unconsolidated affiliates	14	21
SDG&E and SoCalGas | Related Party
Related Party Transaction [Line Items]
Total due to unconsolidated affiliates – current	(59)	(73)
SDG&E and SoCalGas | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Income taxes due from (to) Sempra	38	246
Five Point Five Percent Note Due January 2024 | TAG Pipelines Norte | 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 Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ 0	(24)
Five Point Five Percent Note due July 2025 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ 0	(23)
Five Point Five Percent Note due January 2026 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (8)	(20)
Five Point Five Percent Note due July 2026 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (12)	(11)
Five Point Five Percent Note due January 2027 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (15)	(14)
Five Point Five Percent Note due July 2027 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (19)	(17)
Five Point Five Percent Note Due January 2028 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (48)	0
Five Point Five Percent Note Due July 2028 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.50%
Due to unconsolidated affiliates, noncurrent	$ (41)	0
Five Point Seven Four Percent Note December 2029 | TAG Pipelines Norte | Related Party
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (209)	$ (198)
Five Point Seven Four Percent Note December 2029 | TAG JV Notes | Related Party
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)	5.74%

SIGNIFICANT ACCOUNTING POLIC_10

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) $ in Millions	1 Months Ended		12 Months Ended
	Jan. 31, 2022 MW	Jun. 30, 2015 MW	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Related Party Transaction [Line Items]
Revenues			$ 13,185	$ 16,720	$ 14,439
Interest income			61	89	75
Interest expense			1,049	1,309	1,054
SDG&E
Related Party Transaction [Line Items]
Revenues			5,341	5,597	5,838
Interest income			5	15	5
Interest expense			525	497	449
Operating Revenue			5,341	5,597	5,838
SoCalGas
Related Party Transaction [Line Items]
Revenues			6,209	8,289	6,840
Interest income			9	9	6
Interest expense			323	285	198
Operating Revenue			$ 6,209	8,289	6,840
California Utilities | Minimum
Related Party Transaction [Line Items]
Variable percentage rate			13%
California Utilities | Maximum
Related Party Transaction [Line Items]
Variable percentage rate			20%
Related Party
Related Party Transaction [Line Items]
Revenues			$ 40	44	41
Interest income			0	0	16
Interest expense			16	15	15
Related Party | SDG&E
Related Party Transaction [Line Items]
Cost of sales			146	113	92
Operating Revenue			23	21	16
Related Party | SoCalGas
Related Party Transaction [Line Items]
Cost of sales			(5)	35	(9)
Operating Revenue			$ 169	$ 124	$ 100
ESJ JV | SDG&E
Related Party Transaction [Line Items]
Power purchase agreement term	20 years	20 years
Generating capacity (in mw) | MW	108	155

SIGNIFICANT ACCOUNTING POLIC_11

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Inventory [Line Items]
Natural gas	$ 163	$ 174
LNG	27	9
Materials and supplies	369	299
Total	559	482
SDG&E
Inventory [Line Items]
Natural gas	1	1
LNG	0	0
Materials and supplies	201	152
Total	202	153
SoCalGas
Inventory [Line Items]
Natural gas	148	155
LNG	0	0
Materials and supplies	139	122
Total	$ 287	$ 277

SIGNIFICANT ACCOUNTING POLIC_12

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2019	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2019	Sep. 30, 2019
Loss Contingencies [Line Items]
Noncurrent portion of the Wildfire Fund asset		$ 262	$ 269
SDG&E
Loss Contingencies [Line Items]
Initial liability cap		1,400
Initial shareholder contributions					$ 322.5
Additional annual contributions, aggregate value		129
Wildfire fund asset				$ 451.5
Annual contributions		$ 12.9
Amortization of wildfire fund asset		25 years	15 years
Current portion of Wildfire fund		$ 14	$ 28
Noncurrent portion of the Wildfire Fund asset		262	269
Wildfire fund obligations in current liabilities		13	13
Noncurrent Wildfire Fund obligation		31	$ 42
Wildfire Fund
Loss Contingencies [Line Items]
Wildfire fund, threshold amount to seek payment	$ 1,000
Wildfire fund, threshold percentage of equity portion of electric transmission	20%
Liquidity fund, maximum borrowing capacity		10,500
Initial shareholder contributions		7,500
Additional annual contributions, aggregate value		$ 3,000
Period of annual contributions		10 years

SIGNIFICANT ACCOUNITNG POLICIES

SIGNIFICANT ACCOUNITNG POLICIES AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	1 Months Ended
	Nov. 30, 2021	Dec. 31, 2024	Dec. 31, 2023
Receivables with Imputed Interest [Line Items]
Note receivable issued	$ 300
Note receivable interest rate (as a percent)	5%
Other long-term assets
Receivables with Imputed Interest [Line Items]
Note receivable, net		$ 349	$ 332

SIGNIFICANT ACCOUNTING POLIC_13

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - GOODWILL AND OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,602	$ 1,602
Total intangible assets, gross	440	440
Accumulated amortization	(148)	(122)
Intangible Assets, Net (Excluding Goodwill), Total	292	318
Intangible assets amortization expense	26	26	$ 26
Amortization recorded against revenues	13.5	13.5	$ 13.5
Expected amortization, year one	26
Expected amortization, year two	26
Expected amortization, year three	26
Expected amortization, year four	26
Expected amortization, year five	26
Expected amortization expense, recorded against revenues, year one	13.5
Expected amortization expense, recorded against revenues, year two	13.5
Expected amortization expense, recorded against revenues, year three	13.5
Expected amortization expense, recorded against revenues, year four	13.5
Expected amortization expense, recorded against revenues, year five	13.5
Renewable energy transmission and consumption permits
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	169	169
Accumulated amortization	$ (68)	(59)
Renewable energy transmission and consumption permits | Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	15 years
Renewable energy transmission and consumption permits | Maximum
Finite-Lived Intangible Assets [Line Items]
Amortization period	19 years
O&M agreement
Finite-Lived Intangible Assets [Line Items]
Amortization period	23 years
Intangible assets, gross	$ 66	66
Accumulated amortization	$ (20)	(17)
ESJ PPA
Finite-Lived Intangible Assets [Line Items]
Amortization period	14 years
Intangible assets, gross	$ 190	190
Accumulated amortization	(51)	(37)
Other
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	15	15
Accumulated amortization	$ (9)	$ (9)
Other | Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	10 years

SIGNIFICANT ACCOUNTING POLIC_14

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) segment	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 80,397	$ 72,495
Depreciation expense	2,409	2,202	$ 1,995
Accumulated depreciation	$ 18,960	17,535
Sempra Infrastructure
Property, Plant and Equipment [Line Items]
Number of segments of pipeline | segment	2
SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 33,162	30,918
Depreciation expense	1,216	1,092	977
Accumulated depreciation	8,051	7,369
SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	29,084	27,025
Depreciation expense	903	833	$ 755
Accumulated depreciation	8,330	7,852
Natural gas operations | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 4,531	$ 4,175
Depreciation rates (percentage)	2.62%	2.60%	2.57%
Accumulated depreciation	$ 1,121	$ 1,048
Natural gas operations | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 27,191	$ 25,506
Depreciation rates (percentage)	3.68%	3.64%	3.57%
Accumulated depreciation	$ 8,315	$ 7,835
Electric distribution | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 12,542	$ 11,597
Depreciation rates (percentage)	4.21%	4.05%	3.94%
Electric transmission | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 8,878	$ 8,504
Depreciation rates (percentage)	3.06%	3.04%	3.03%
Electric generation | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 2,527	$ 2,515
Depreciation rates (percentage)	5.43%	5.18%	5.11%
Other electric | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 2,722	$ 2,507
Depreciation rates (percentage)	6.95%	7.05%	7.03%
Other non-utility | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 32	$ 50
Depreciation rates (percentage)	0.98%	1.03%	1.54%
Accumulated depreciation	$ 15	$ 17
Other non-utility | Other Sempra
Property, Plant and Equipment [Line Items]
Accumulated depreciation	2,579	2,314
Land and land rights | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 498	488
Land and land rights | Minimum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	16 years
Land and land rights | Maximum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	44 years
Land and land rights | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	37 years
Pipelines and storage
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,313	1,304
Pipelines and storage | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 4,355	3,883
Pipelines and storage | Minimum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	41 years
Pipelines and storage | Maximum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	49 years
Pipelines and storage | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	42 years
Generating plants | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,820	1,815
Generating plants | Minimum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	11 years
Generating plants | Maximum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	28 years
Generating plants | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	26 years
LNG terminal | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,156	1,139
Estimated useful life (in years)	42 years
LNG terminal | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	42 years
Refined products terminals | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 876	656
Estimated useful life (in years)	37 years
Refined products terminals | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	37 years
Other | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 348	346
Other | Minimum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	1 year
Other | Maximum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	21 years
Other | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	15 years
Construction work in progress | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,962	1,620
Construction work in progress | SoCalGas
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,861	1,469
Construction work in progress | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	8,781	5,930
Other | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 317	295
Other | Minimum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	1 year
Other | Maximum | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	35 years
Other | Weighted Average | Other Sempra
Property, Plant and Equipment [Line Items]
Estimated useful life (in years)	16 years
Total Sempra Infrastructure and Parent | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 18,151	14,552
Plant, pipeline and other distribution assets of Ecogas | Other Sempra
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	290	310
Accumulated depreciation	75	82
Electric transmission, distribution and generation | SDG&E
Property, Plant and Equipment [Line Items]
Accumulated depreciation	6,930	$ 6,321
Guaymas-El Oro segment of the Sonora Pipeline | Sempra Infrastructure
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	401
Southwest Powerlink (SWPL) transmission line | Electric transmission | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	563
Accumulated depreciation	338
Southwest Powerlink (SWPL) transmission line | Construction work in progress | SDG&E
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1
Southwest Powerlink | Southwest Powerlink (SWPL) transmission line | Electric transmission | SDG&E
Property, Plant and Equipment [Line Items]
Ownership interest (as a percent)	86%

SIGNIFICANT ACCOUNTING POLIC_15

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 629	$ 448	$ 255
SDG&E
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	100	116	116
SoCalGas
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 101	$ 77	$ 73

SIGNIFICANT ACCOUNTING POLIC_16

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 3,831	$ 3,712	$ 3,538
Accretion expense	156	148	141
Liabilities incurred	0	18	21
Payments	(65)	(62)	(57)
Revisions	3	15	69
Ending Balance	3,925	3,831	3,712
SDG&E
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	894	887	890
Accretion expense	37	37	37
Liabilities incurred	0	15	6
Payments	(57)	(59)	(54)
Revisions	26	14	8
Ending Balance	900	894	887
SoCalGas
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2,847	2,743	2,582
Accretion expense	114	106	101
Liabilities incurred	0	0	0
Payments	(8)	(3)	(3)
Revisions	(23)	1	63
Ending Balance	$ 2,930	$ 2,847	$ 2,743

SIGNIFICANT ACCOUNTING POLIC_17

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 28,675
Total other comprehensive income, net of tax amount, attributable to parent	(16)	$ 31	$ 174
Ending balance	31,222	28,675
AOCI associated with noncontrolling interests	11	(28)	54
SDG&E
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	9,902
Total other comprehensive income, net of tax amount, attributable to parent	(4)	(1)	3
Ending balance	10,564	9,902
SoCalGas
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	7,410	6,698	5,442
Total other comprehensive income, net of tax amount, attributable to parent	(4)	1	7
Ending balance	8,161	7,410	6,698
Accumulated other comprehensive income (loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(150)	(135)	(318)
OCI before reclassifications	3	47	146
Amounts reclassified from AOCI	(19)	(62)	37
Total other comprehensive income, net of tax amount, attributable to parent	(16)	(15)	183
Ending balance	(166)	(150)	(135)
Accumulated other comprehensive income (loss) | SDG&E
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(8)	(7)	(10)
OCI before reclassifications	(3)	(2)	2
Amounts reclassified from AOCI	(1)	1	1
Total other comprehensive income, net of tax amount, attributable to parent	(4)	(1)	3
Ending balance	(12)	(8)	(7)
Accumulated other comprehensive income (loss) | SoCalGas
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(23)	(24)	(31)
OCI before reclassifications	(5)	(1)	4
Amounts reclassified from AOCI	1	2	3
Total other comprehensive income, net of tax amount, attributable to parent	(4)	1	7
Ending balance	(27)	(23)	(24)
Foreign currency translation adjustments
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(36)	(59)	(79)
OCI before reclassifications	(30)	23	10
Amounts reclassified from AOCI	0	0	10
Total other comprehensive income, net of tax amount, attributable to parent	(30)	23	20
Ending balance	(66)	(36)	(59)
AOCI associated with noncontrolling interests			9
Financial instruments
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	3	10	(156)
OCI before reclassifications	34	59	147
Amounts reclassified from AOCI	(22)	(66)	19
Total other comprehensive income, net of tax amount, attributable to parent	12	(7)	166
Ending balance	15	3	10
AOCI associated with noncontrolling interests		(46)
Financial instruments | SoCalGas
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(11)	(12)	(13)
OCI before reclassifications	0	0	0
Amounts reclassified from AOCI	1	1	1
Total other comprehensive income, net of tax amount, attributable to parent	1	1	1
Ending balance	(10)	(11)	(12)
Pension and PBOP
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(117)	(86)	(83)
OCI before reclassifications	(1)	(35)	(11)
Amounts reclassified from AOCI	3	4	8
Total other comprehensive income, net of tax amount, attributable to parent	2	(31)	(3)
Ending balance	(115)	(117)	(86)
Pension and PBOP | SDG&E
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(8)	(7)	(10)
OCI before reclassifications	(3)	(2)	2
Amounts reclassified from AOCI	(1)	1	1
Total other comprehensive income, net of tax amount, attributable to parent	(4)	(1)	3
Ending balance	(12)	(8)	(7)
Pension and PBOP | SoCalGas
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(12)	(12)	(18)
OCI before reclassifications	(5)	(1)	4
Amounts reclassified from AOCI	0	1	2
Total other comprehensive income, net of tax amount, attributable to parent	(5)	0	6
Ending balance	$ (17)	$ (12)	$ (12)

SIGNIFICANT ACCOUNTING POLIC_18

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and maintenance	$ 5,336	$ 5,458	$ 4,746
Interest expense	(1,049)	(1,309)	(1,054)
Equity earnings	1,609	1,481	1,498
Energy-related businesses	1,748	2,891	1,788
Other income (expense), net	136	131	24
Income before income taxes and equity earnings	2,110	2,627	1,343
Income tax (expense) benefit	(219)	(490)	(556)
Earnings attributable to noncontrolling interests	(638)	(543)	(146)
Total, net of income tax and after NCI	2,862	3,075	2,139
Net income	3,500	3,618	2,285
SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(525)	(497)	(449)
Other income (expense), net	90	97	92
Income before income taxes and equity earnings	1,044	910	1,097
Income tax (expense) benefit	(153)	26	(182)
Total, net of income tax and after NCI	891	936	915
Net income	891	936	915
SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(323)	(285)	(198)
Other income (expense), net	25	(4)	(8)
Income before income taxes and equity earnings	987	807	738
Income tax (expense) benefit	(31)	5	(138)
Total, net of income tax and after NCI	956	812	600
Net income	956	812	600
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, net of income tax and after NCI	(19)	(16)	28
Reclassification out of Accumulated Other Comprehensive Income | SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, net of income tax and after NCI	(1)	1	1
Reclassification out of Accumulated Other Comprehensive Income | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, net of income tax and after NCI	1	2	3
Reclassification out of Accumulated Other Comprehensive Income | Foreign currency translation adjustments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and maintenance	0	0	1
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	18	5	11
Income tax (expense) benefit	(15)	(1)	(3)
Income (loss) from continuing operations, net of tax	3	4	8
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits | SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	1	1	1
Income tax (expense) benefit	(2)	0	0
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	2	2	3
Income tax (expense) benefit	(2)	(1)	(1)
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	6	3	7
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss | SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	1	0	1
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	1	1	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 (expense), net	3	2	4
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost | SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	0	1	0
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 (expense), net	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | Settlement charges
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	9	0	0
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, net of income tax and after NCI	(22)	(20)	19
Reclassification out of Accumulated Other Comprehensive Income | Financial instruments | Interest rate instruments | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	1	1
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income (expense), net	0	(6)	(12)
Income before income taxes and equity earnings	(47)	(49)	16
Income tax (expense) benefit	11	6	(6)
Income (loss) from continuing operations, net of tax	(36)	(43)	10
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest | SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income	0	1	2
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	(11)	1	1
Equity earnings	(23)	(48)	29
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	(6)	2	0
Energy-related businesses	(5)	1	(1)
Other income (expense), net	(2)	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)	(2)
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	$ 14	$ 23	$ 9

SIGNIFICANT ACCOUNTING POLIC_19

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INCOME (EXPENSE), NET (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Other Income [Line Items]
Allowance for equity funds used during construction	$ 150	$ 140	$ 143
Investment gains (losses), net	36	28	(42)
Gains on interest rate and foreign exchange instruments, net	2	4	11
Foreign currency transaction gains (losses), net	(16)	2	(24)
Non-service components of net periodic benefit cost	(101)	(106)	(59)
Interest on regulatory balancing accounts, net	75	79	26
Sundry, net	(10)	(16)	(31)
Total	136	131	24
SDG&E
Other Income [Line Items]
Allowance for equity funds used during construction	73	86	88
Non-service components of net periodic benefit cost	4	(19)	(11)
Interest on regulatory balancing accounts, net	23	42	18
Sundry, net	(10)	(12)	(3)
Total	90	97	92
SoCalGas
Other Income [Line Items]
Allowance for equity funds used during construction	72	54	55
Non-service components of net periodic benefit cost	(86)	(80)	(42)
Interest on regulatory balancing accounts, net	52	37	8
Sundry, net	(13)	(15)	(29)
Total	$ 25	$ (4)	(8)
IMG JV
Other Income [Line Items]
Foreign currency transaction gains (losses), net			$ (11)

SIGNIFICANT ACCOUNTING POLIC_20

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RESTRICTED NET ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Significant Restrictions of Subsidiaries [Line Items]
Undistributed earnings from equity method investments	$ 2,900	$ 2,500
Maximum ratio of indebtedness to total capitalization	0.65
Cameron LNG
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50.20%
Indirect economic and beneficial and ownership interest after financial completion	10%
Sharyland Holdings, LP
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50%
Oncor Holdings | Oncor Holdings
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	100%
Oncor Holdings | Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	80.25%
Sempra Texas Utilities | Oncor Holdings
Significant Restrictions of Subsidiaries [Line Items]
Plan percentage of capital structure allocated to equity	42.50%
Plan percentage of capital structure allocated to debt	57.50%
Sempra Texas Utilities | Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Maximum ratio of indebtedness to total capitalization	0.65
Sempra Infrastructure | Cameron LNG
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50.20%
Consolidated Entities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 17,900
Unconsolidated Entities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	16,300
SDG&E
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	10,000
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 672
Plan percentage of capital structure allocated to equity	52%
Maximum ratio of indebtedness to total capitalization	0.65
SoCalGas
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 7,700
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 457
Plan percentage of capital structure allocated to equity	52%
Maximum ratio of indebtedness to total capitalization	0.65
Sempra Texas Utilities | Sharyland Utilities
Significant Restrictions of Subsidiaries [Line Items]
Maximum ratio of indebtedness to total capitalization	0.70
Plan percentage of capital structure allocated to debt	60%
Sempra Texas Utilities | Sharyland Holdings, LP | Sharyland Holdings, LP
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50%
Sempra Texas Utilities | Sharyland Holdings, LP | Sharyland Utilities
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	100%
Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 15,600
Port Arthur LNG
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 19
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due March 2030 | Line of Credit
Significant Restrictions of Subsidiaries [Line Items]
Term of contract (in years)	7 years
Sharyland Utilities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 136
Cameron LNG JV | Sempra Infrastructure
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	443
Mexican Subsidiaries | Sempra Infrastructure
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	185
Gasoductos De Chihuahua [Member] | Sempra Infrastructure
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	3
TAG Pipelines Norte | Sempra Infrastructure
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 126
TAG Pipelines Norte | Sempra Infrastructure | Cameron LNG
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50%

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 11,818	$ 14,848	$ 13,722
Utilities regulatory revenues	374	75	633
Other revenues	993	1,797	84
Total revenues	13,185	16,720	14,439
Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	13,264	16,832	14,496
Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,008	13,686	11,944
Utilities regulatory revenues	374	75	633
Other revenues	0	0	0
Total revenues	11,382	13,761	12,577
Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	896	1,251	1,849
Utilities regulatory revenues	0	0	0
Other revenues	986	1,820	70
Total revenues	1,882	3,071	1,919
Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(86)	(89)	(71)
Utilities regulatory revenues	0	0	0
Other revenues	7	(23)	14
Total revenues	(79)	(112)	(57)
SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,042	5,954	5,586
Utilities regulatory revenues	299	(357)	252
Total revenues	5,341	5,597	5,838
SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,134	7,857	6,459
Utilities regulatory revenues	75	432	381
Total revenues	6,209	8,289	6,840
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,063	13,754	12,018
Utilities | Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,008	13,686	11,944
Utilities | Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	78	87	89
Utilities | Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(23)	(19)	(15)
Utilities | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,042	5,954	5,586
Utilities | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,134	7,857	6,459
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	755	1,094	1,704
Energy-related businesses | Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Energy-related businesses | Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	818	1,164	1,760
Energy-related businesses | Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(63)	(70)	(56)
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	7,308	9,687	8,525
Gas | Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,858	8,949	7,267
Gas | Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	471	755	1,270
Gas | Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(21)	(17)	(12)
Gas | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	878	1,204	899
Gas | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,134	7,857	6,459
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,510	5,161	5,197
Electric | Operating Segments | Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,150	4,737	4,677
Electric | Operating Segments | Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	425	496	579
Electric | Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(65)	(72)	(59)
Electric | SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,164	4,750	4,687
Electric | SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 0	$ 0	$ 0

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Dec. 31, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 3,523
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]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 403
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	$ 284
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	$ 285
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	$ 239
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	$ 211
Revenues to be recognized, period of recognition	1 year
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	$ 4
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 2,101
Revenues to be recognized, period of recognition
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | SDG&E
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 52
Revenues to be recognized, period of recognition

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Contract with Customer, Liability [Roll Forward]
Beginning balance		$ (198)	$ (252)	$ (278)
Revenue from performance obligations satisfied during reporting period		11	14	131
Payments received in advance		(7)	(21)	(105)
Contract modification	$ 61	(2)	61	0
Ending balance	(198)	(196)	(198)	(252)
Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Beginning balance		(5)
Ending balance	(5)	(105)	(5)
Deferred credits and other
Contract with Customer, Liability [Roll Forward]
Beginning balance		(193)
Ending balance	(193)	(91)	(193)
SDG&E
Contract with Customer, Liability [Roll Forward]
Beginning balance		(75)	(79)	(83)
Revenue from performance obligations satisfied during reporting period		3	4	4
Ending balance	(75)	(72)	(75)	$ (79)
SDG&E | Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Beginning balance		(3)
Ending balance	(3)	(4)	(3)
SDG&E | Deferred credits and other
Contract with Customer, Liability [Roll Forward]
Beginning balance		(72)
Ending balance	$ (72)	$ (68)	$ (72)

REVENUES - Narrative (Details)

REVENUES - Narrative (Details) - USD ($) $ in Millions	1 Months Ended
	Dec. 31, 2024	Nov. 30, 2024
Revenue from Contract with Customer [Abstract]
Revenue, Change in Judgment, Revenue Recognition Period	1 year	3 years
Revenue, Change in Judgment, Increase in Revenue Due to Contract Modification	$ 107

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,821	$ 1,970
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,787	1,951
Accounts receivable – trade, net | Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	144	148
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	12	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	18	0
SDG&E
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	795	889
SDG&E | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	774	870
SDG&E | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	11	13
SDG&E | Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	6
SDG&E | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	4	0
SoCalGas
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	947	987
SoCalGas | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	932	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	Dec. 31, 2024	Dec. 31, 2023
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 39	$ (295)
Regulatory balancing accounts - net undercollected, Noncurrent	1,731	1,913
Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(458)	(212)
Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(3,295)	(3,082)
Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(313)	(233)
Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(47)	(259)
Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(439)	(273)
Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(24)
Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)		(10)
Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	53	215
Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	1,689	1,142
Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	19	24
Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	149	139
Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	124	124
Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	820	959
2024 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	631	0
Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	808	685
Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)		113
Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	158	373
Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	164
SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(736)	(994)
Regulatory balancing accounts - net undercollected, Noncurrent	873	950
SDG&E | Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2)
SDG&E | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,676)	(2,468)
SDG&E | Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(313)	(233)
SDG&E | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(219)	(144)
SDG&E | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(15)
SDG&E | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(51)	(152)
SDG&E | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	11	14
SDG&E | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	802	626
SDG&E | Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)		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)	124	124
SDG&E | Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	86	52
SDG&E | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	227	207
SDG&E | 2024 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	277	0
SDG&E | Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	808	685
SDG&E | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)		90
SDG&E | Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	87	49
SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	707	614
Regulatory balancing accounts - net undercollected, Noncurrent	858	963
SoCalGas | Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(456)	(260)
SoCalGas | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(619)	(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)	(133)	(311)
SoCalGas | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(220)	(129)
SoCalGas | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(9)
SoCalGas | Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)		(58)
SoCalGas | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	42	201
SoCalGas | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	817	430
SoCalGas | Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	16	21
SoCalGas | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	34	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)	593	752
SoCalGas | 2024 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	354	0
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)		23
SoCalGas | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	209	$ 525
SoCalGas | Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 79

REGULATORY MATTERS - REGULATROY

REGULATORY MATTERS - REGULATROY ASSETS NOT EARNING A RETURN AND EARNING A RETURN (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Amortization of regulatory asset	$ 14	$ 12	$ 11
SDG&E
Public Utilities, General Disclosures [Line Items]
Amortization of regulatory asset	$ 7	6	5
SDG&E | Sunrise Powerlink fire mitigation
Public Utilities, General Disclosures [Line Items]
Amortization period (in years)	45 years
SoCalGas
Public Utilities, General Disclosures [Line Items]
Amortization of regulatory asset	$ 7	$ 6	$ 6
Minimum
Public Utilities, General Disclosures [Line Items]
Amortization period (in years)	5 years
Maximum
Public Utilities, General Disclosures [Line Items]
Regulatory asset, recovery (in years)	4 years
Amortization period (in years)	69 years

REGULATORY MATTERS - CPUC GRC (

REGULATORY MATTERS - CPUC GRC (Details) - General Rate Case - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2024	Oct. 31, 2023	Dec. 31, 2027	Dec. 31, 2026	Dec. 31, 2025	Dec. 31, 2024
2024 GRC - 2024 Requirement | SDG&E
Public Utilities, General Disclosures [Line Items]
General rate case, requested review and recovery of wildfire mitigation plan costs		$ 1,500
General rate case, expected recovery of wildlife mitigation plan costs						$ 194
2024 GRC - 2024 Requirement | SDG&E | Forecast
Public Utilities, General Disclosures [Line Items]
General rate case, expected recovery of wildlife mitigation plan costs					$ 96
2024 General Rate Case | SDG&E | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Approved revenue requirement	$ 2,699
Approved revenue increase from prior request	$ 189
Approved revenue increase from prior request (percent)	7.50%
Net income tax benefits	$ 68
Approved rate of return	0.0745
2024 General Rate Case | SDG&E | California Public Utilities Commission | Natural Gas Operations
Public Utilities, General Disclosures [Line Items]
Approved revenue requirement	$ 506
2024 General Rate Case | SDG&E | California Public Utilities Commission | Electrical Operations
Public Utilities, General Disclosures [Line Items]
Approved revenue requirement	2,193
2024 General Rate Case | SDG&E | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Approved revenue increase from prior request			$ 122	$ 119	$ 147
Approved revenue increase from prior request (percent)			4.11%	4.17%	5.45%
2024 General Rate Case | SoCalGas | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Approved revenue requirement	3,806
Approved revenue increase from prior request	$ 324
Approved revenue increase from prior request (percent)	9.30%
Net income tax benefits	$ 202
Approved rate of return	0.0749
2024 General Rate Case | SoCalGas | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Approved revenue increase from prior request			$ 120	$ 116	$ 190
Approved revenue increase from prior request (percent)			2.92%	2.91%	5%

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL & ENERGY EFFICIENCY (Details)		1 Months Ended	12 Months Ended				36 Months Ended
	Jan. 01, 2025	Oct. 31, 2024	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2022
2024 General Rate Case | Cost of Capital Proceeding
Public Utilities, General Disclosures [Line Items]
Approved decrease adjustment to ROE		20%
Return on rate base (as a percent)					50%
California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate, variable rate (as a percent)							1%
SDG&E | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Authorized weighting, total (as a percent)				100%
Weighted return on rate base, total (as a percent)				7.67%	7.18%	7.55%
SDG&E | California Public Utilities Commission | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)	10.23%
SDG&E | California Public Utilities Commission | 2024 General Rate Case | Cost of Capital Proceeding
Public Utilities, General Disclosures [Line Items]
Decrease adjustment to ROE		0.42%
SDG&E | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base, total (as a percent)			7.45%
SDG&E | Authorized weighting | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				45.25%
SDG&E | Authorized weighting | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				2.75%
SDG&E | Authorized weighting | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				52%
SDG&E | Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				4.34%	4.05%	4.59%
SDG&E | Return on Rate Base | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt			4.34%
SDG&E | Return on Rate Base | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				6.22%	6.22%	6.22%
SDG&E | Return on Rate Base | Preferred Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			6.22%
SDG&E | Return on Rate Base | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				10.65%	9.95%	10.20%
SDG&E | Return on Rate Base | Common Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			10.23%
SDG&E | Weighted Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				1.96%	1.83%	2.08%
SDG&E | Weighted Return on Rate Base | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt			1.96%
SDG&E | Weighted Return on Rate Base | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				0.17%	0.17%	0.17%
SDG&E | Weighted Return on Rate Base | Preferred Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			0.17%
SDG&E | Weighted Return on Rate Base | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				5.54%	5.17%	5.30%
SDG&E | Weighted Return on Rate Base | Common Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			5.32%
SoCalGas | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Authorized weighting, total (as a percent)				100%
Weighted return on rate base, total (as a percent)				7.67%	7.10%	7.30%
SoCalGas | California Public Utilities Commission | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)	10.08%
SoCalGas | California Public Utilities Commission | 2024 General Rate Case | Cost of Capital Proceeding
Public Utilities, General Disclosures [Line Items]
Decrease adjustment to ROE		0.42%
SoCalGas | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base, total (as a percent)			7.49%
SoCalGas | Authorized weighting | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				45.60%
SoCalGas | Authorized weighting | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				2.40%
SoCalGas | Authorized weighting | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				52%
SoCalGas | Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				4.54%	4.07%	4.23%
SoCalGas | Return on Rate Base | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt			4.63%
SoCalGas | Return on Rate Base | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				6%	6%	6%
SoCalGas | Return on Rate Base | Preferred Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			6%
SoCalGas | Return on Rate Base | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				10.50%	9.80%	10.05%
SoCalGas | Return on Rate Base | Common Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			10.08%
SoCalGas | Weighted Return on Rate Base | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt				2.07%	1.86%	1.93%
SoCalGas | Weighted Return on Rate Base | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt			2.11%
SoCalGas | Weighted Return on Rate Base | Preferred Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				0.14%	0.14%	0.14%
SoCalGas | Weighted Return on Rate Base | Preferred Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			0.14%
SoCalGas | Weighted Return on Rate Base | Common Equity | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				5.46%	5.10%	5.23%
SoCalGas | Weighted Return on Rate Base | Common Equity | Forecast | California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)			5.24%

REGULATORY MATTERS - FERC Rate

REGULATORY MATTERS - FERC Rate Matters (Details) - SDG&E - FERC - USD ($) $ in Millions	1 Months Ended
	Dec. 31, 2024	Oct. 31, 2024	Sep. 30, 2024
TO5 Settlement
Public Utilities, General Disclosures [Line Items]
Minimum common equity ratio (as a percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
Settlement charges	$ 120
Settlement charges, net	89
TO5 Settlement | Electric Revenues
Public Utilities, General Disclosures [Line Items]
Settlement charges	94
TO5 Settlement | Other Income, Net
Public Utilities, General Disclosures [Line Items]
Settlement charges	$ 26
TO6 Filing
Public Utilities, General Disclosures [Line Items]
Minimum common equity ratio (as a percent)	12.25%
FERC requirement to maintain common equity ratio at or above, base (as a percent)		11.75%	10.10%

SEMPRA _ INVESTMENTS IN UNCON_3

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 15,400	$ 14,266
Other investments	2,534	2,244
Goodwill	1,602	1,602
Earnings recorded before tax	603	633	$ 666
Equity earnings	1,609	1,481	1,498
Payments to acquire equity method investments	988	382	376
Distributions from Investments	1,177	948	886
Undistributed earnings from equity method investments	2,900	2,500
Undistributed earnings, equity method investments, less than 50 percent owned	630
Operating Segments
Schedule of Equity Method Investments [Line Items]
Other investments	2,533	2,243
Earnings recorded before tax	584	593	666
Earnings recorded net of income tax	1,006	848	832
Distributions from Investments	1,168	948	886
Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	12	15	30
Sempra Infrastructure | Operating Segments
Schedule of Equity Method Investments [Line Items]
Equity earnings	802	740	756
Distributions from Investments	548	503	541
Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	976	367	346
Sempra Texas Utilities | Operating Segments
Schedule of Equity Method Investments [Line Items]
Equity earnings	788	701	742
Distributions from Investments	620	445	345
Total
Schedule of Equity Method Investments [Line Items]
Other investments	2,534	2,244
Oncor Holdings | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	$ 972	$ 363	341
Oncor Holdings | Sempra Texas Utilities | Operating Segments
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100%	100%
Equity method investment	$ 15,400	$ 14,266
Difference between carrying amount of equity method investment and underlying equity	2,884	2,870
Goodwill	2,868	2,868
Equity method investment, difference between carrying amount and underlying equity, aoci	69	69
Difference between carrying amount and underlying equity, tax sharing liability	53	67
Earnings recorded net of income tax	780	694	735
Distributions from Investments	616	441	340
Return of investments	13
Total distributions from equity method investments, including the tax sharing agreement	$ 681	558	443
Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50%
Sharyland Holdings, LP | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments	$ 4	$ 4	5
Sharyland Holdings, LP | Sempra Texas Utilities | Operating Segments
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50%	50%
Other investments	$ 122	$ 114
Difference between carrying amount of equity method investment and underlying equity	41	41
Earnings recorded before tax	8	7	7
Distributions from Investments	4	4	5
Cameron LNG JV | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Equity method investment	1,149	1,008
Payments to acquire equity method investments	$ 12	$ 15	30
Cameron LNG JV | Sempra Infrastructure | Operating Segments
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%	50.20%
Other investments	$ 1,149	$ 1,008
Difference between carrying amount of equity method investment and underlying equity	257	262
Earnings recorded before tax	576	586	659
Basis difference in equity earnings related to AOCI		9	12
Distributions from Investments	$ 453	$ 456	509
IMG JV | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40%
IMG JV | Sempra Infrastructure | Operating Segments
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40%	40%
Other investments	$ 723	$ 620
Difference between carrying amount of equity method investment and underlying equity	5	5
Earnings recorded net of income tax	136	40	68
Distributions from Investments	$ 33	$ 11	0
TAG Pipelines Norte | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50%
TAG Pipelines Norte | Sempra Infrastructure | Operating Segments
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50%	50%
Other investments	$ 539	$ 501
Difference between carrying amount of equity method investment and underlying equity	130	130
Earnings recorded net of income tax	90	114	29
Distributions from Investments	62	36	32
RBS Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Earnings recorded before tax	19	40
RBS Sempra Commodities | Parent and other
Schedule of Equity Method Investments [Line Items]
Earnings recorded before tax	19	40	0
Distributions from Investments	9	0	$ 0
Other | Parent and other
Schedule of Equity Method Investments [Line Items]
Other investments	$ 1	$ 1

SEMPRA _ INVESTMENTS IN UNCON_4

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - ONCOR HOLDINGS (Details)	Dec. 31, 2024
Oncor Holdings | Oncor Electric Delivery Company LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners	80.25%
Oncor Holdings | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100%

SEMPRA _ INVESTMENTS IN UNCON_5

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Interest expense	$ (1,049)	$ (1,309)	$ (1,054)
Income tax expense	(219)	(490)	(556)
Net income	3,500	3,618	2,285
Earnings attributable to noncontrolling interests	(638)	(543)	(146)
Earnings attributable to common shares	2,817	3,030	2,094
Total current assets	5,285	5,470
Current liabilities	9,676	10,090
Oncor Holdings | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Operating revenues	6,082	5,586	5,243
Operating expenses	(4,318)	(4,026)	(3,682)
Operating income (loss)	1,764	1,560	1,561
Interest expense	(653)	(536)	(445)
Income tax expense	(217)	(192)	(203)
Net income	957	849	893
Earnings attributable to noncontrolling interests	(192)	(170)	(179)
Earnings attributable to common shares	765	679	$ 714
Total current assets	1,638	1,431
Noncurrent assets	38,697	34,649
Current liabilities	2,183	1,625
Noncurrent liabilities	21,958	19,727
NCI held by TTI	$ 3,689	$ 3,338

SEMPRA _ INVESTMENTS IN UNCON_6

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - SHARYLAND HOLDINGS (Details)	Dec. 31, 2024
Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50%
Sharyland Utilities | Sharyland Holdings, LP | Sharyland Utilities
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	100%

SEMPRA _ INVESTMENTS IN UNCON_7

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - CAMERON LNG JV (Details) - Cameron LNG	Dec. 31, 2024
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%
Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%

SEMPRA _ INVESTMENTS IN UNCON_8

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - SEMPRA PROMISSORY NOTE FOR SDSRA DISTRIBUTION (Details) - Cameron LNG - Corporate Joint Venture - Sempra Infrastructure - Promissory Note for SDSRA Distribution - USD ($) $ in Millions	1 Months Ended
	Jun. 30, 2021	Dec. 31, 2024
Schedule of Equity Method Investments [Line Items]
Cash dividends received	$ 165
Deferred Credits and Other
Schedule of Equity Method Investments [Line Items]
Guaranty liability	$ 22	$ 18

SEMPRA _ INVESTMENTS IN UNCON_9

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - SEMPRA SUPPORT AGREEMENT FOR CFIN, IMG, AND TAG NORTE (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2020 USD ($) projectOwner bank project_owner	Dec. 31, 2024 USD ($)
Cameron LNG
Schedule of Equity Method Investments [Line Items]
Number of project owners | project_owner	4
Cameron LNG
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		50.20%
Cameron LNG | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		50.20%
Cameron LNG | Sempra Infrastructure | TAG Pipelines Norte
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		50%
Cameron LNG | Corporate Joint Venture | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Proceeds from related parties	$ 1,500
Number of project owners sending direct proceeds | projectOwner	2
Number of project owners sending proceeds from external lenders | projectOwner	2
Debt covenant, liability cap (as a percent)		130%
Debt covenant, liability cap amount		$ 979
IMG JV | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		40%
Transportation service contract term		35 years
TAG Pipelines Norte | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		50%
Los Ramones Norte | Sempra Infrastructure | TAG Pipelines Norte
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee		50%
Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Current guarantor obligations		$ 25
Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure | Other Current Assets
Schedule of Equity Method Investments [Line Items]
Current guarantor obligations		7
Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure | Other long-term assets
Schedule of Equity Method Investments [Line Items]
Current guarantor obligations		$ 18
Variable Interest Entity, Not Primary Beneficiary | Cameron LNG | Corporate Joint Venture | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Proceeds from related parties	$ 753
Number of banks | bank	8

SEMPRA _ INVESTMENTS IN UNCO_10

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - RBS SEMPRA COMMODITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Equity earnings	$ 603	$ 633	$ 666
Equity earnings	1,609	1,481	$ 1,498
RBS Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Equity earnings	19	$ 40
Equity in earnings of subsidiaries, net of income taxes	$ 16

SEMPRA _ INVESTMENTS IN UNCO_11

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES - Other Equity Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Interest expense	$ (1,049)	$ (1,309)	$ (1,054)
Net income	3,500	3,618	2,285
Total current assets	5,285	5,470
Current liabilities	9,676	10,090
Other
Schedule of Equity Method Investments [Line Items]
Gross revenues	2,962	3,083	2,959
Operating expenses	(820)	(776)	(772)
Operating income (loss)	2,142	2,307	2,187
Interest expense	(547)	(570)	(505)
Net income	1,688	1,499	$ 1,537
Total current assets	1,134	1,216
Noncurrent assets	14,687	14,826
Current liabilities	1,130	1,255
Noncurrent liabilities	$ 10,051	$ 10,786

DEBT AND CREDIT FACILITIES - CO

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT NARRATIVE (Details)	12 Months Ended
	Dec. 31, 2024 USD ($) lender lineOfCredit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900,000,000
Primary committed lines of credit | lineOfCredit	7
Number of lenders | lender	23
Lenders, percent of facility	6%
Committed lines of credit, capacity for issuance of letters of credit	$ 200,000,000
Line of credit, increase limit	$ 500,000,000
Maximum ratio of indebtedness to total capitalization	0.65
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 4,000,000,000
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500,000,000
Committed lines of credit, capacity for issuance of letters of credit	100,000,000
Line of credit, increase limit	$ 250,000,000
Maximum ratio of indebtedness to total capitalization	0.65
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,200,000,000
Committed lines of credit, capacity for issuance of letters of credit	150,000,000
Line of credit, increase limit	$ 250,000,000
Maximum ratio of indebtedness to total capitalization	0.65
SI Partners and IEnova
Line of Credit Facility [Line Items]
Number of lines of credit | lineOfCredit	3
SI Partners and IEnova | IEnova And SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 500,000,000
Variable percentage rate	0.80%
SI Partners and IEnova | IEnova Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,000,000,000
Number of lenders | lender	12
Variable percentage rate	0.10%
SI Partners and IEnova | IEnova And SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,500,000,000
Variable percentage rate	0.90%
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due March 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 200,000,000
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due March 2030 | Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 200,000,000
Term of contract (in years)	7 years
SI Partners
Line of Credit Facility [Line Items]
Primary committed lines of credit | lineOfCredit	3
Committed lines of credit, capacity for issuance of letters of credit	$ 200,000,000
Maximum adjustment EBITDA allowed	5.25
SI Partners | Swingline Sub-Limit
Line of Credit Facility [Line Items]
Line of credit outstanding	$ 100,000,000
SI Partners | IEnova And SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,500,000,000
Number of lenders | lender	12
IEnova | IEnova Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 910,000,000
Number of lenders | lender	11
IEnova | IEnova And SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,365,000,000
Number of lenders | lender	11

DEBT AND CREDIT FACILITIES - _2

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details)	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 9,900,000,000
Available unused credit	8,528,000,000
Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	(64,000,000)
Commercial Paper
Debt Instrument [Line Items]
Line of credit outstanding	(754,000,000)
Amounts Outstanding
Debt Instrument [Line Items]
Line of credit outstanding	(554,000,000)
Sempra
Debt Instrument [Line Items]
Maximum borrowing capacity	4,000,000,000
Available unused credit	4,000,000,000
Sempra | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
Sempra | Commercial Paper
Debt Instrument [Line Items]
Line of credit outstanding	0
Sempra | Amounts Outstanding
Debt Instrument [Line Items]
Line of credit outstanding	0
SDG&E
Debt Instrument [Line Items]
Maximum borrowing capacity	1,500,000,000
Available unused credit	1,083,000,000
SDG&E | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
SDG&E | Commercial Paper
Debt Instrument [Line Items]
Line of credit outstanding	(417,000,000)
SDG&E | Amounts Outstanding
Debt Instrument [Line Items]
Line of credit outstanding	0
SoCalGas
Debt Instrument [Line Items]
Maximum borrowing capacity	1,200,000,000
Available unused credit	863,000,000
SoCalGas | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
SoCalGas | Commercial Paper
Debt Instrument [Line Items]
Line of credit outstanding	(337,000,000)
SoCalGas | Amounts Outstanding
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova And SI Partners Committed Line Of Credit Due September 2025
Debt Instrument [Line Items]
Maximum borrowing capacity	500,000,000
Available unused credit	132,000,000
SI Partners and IEnova | IEnova And SI Partners Committed Line Of Credit Due September 2025 | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova Committed Line Of Credit Due August 2026
Debt Instrument [Line Items]
Maximum borrowing capacity	1,000,000,000
Available unused credit	1,000,000,000
SI Partners and IEnova | IEnova Committed Line Of Credit Due August 2026 | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | IEnova Committed Line Of Credit Due August 2028
Debt Instrument [Line Items]
Maximum borrowing capacity	1,500,000,000
Available unused credit	1,314,000,000
SI Partners and IEnova | IEnova Committed Line Of Credit Due August 2028 | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial Paper | IEnova And SI Partners Committed Line Of Credit Due September 2025
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial Paper | IEnova Committed Line Of Credit Due August 2026
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Commercial Paper | IEnova Committed Line Of Credit Due August 2028
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Amounts Outstanding | IEnova And SI Partners Committed Line Of Credit Due September 2025
Debt Instrument [Line Items]
Line of credit outstanding	(368,000,000)
SI Partners and IEnova | Amounts Outstanding | IEnova Committed Line Of Credit Due August 2026
Debt Instrument [Line Items]
Line of credit outstanding	0
SI Partners and IEnova | Amounts Outstanding | IEnova Committed Line Of Credit Due August 2028
Debt Instrument [Line Items]
Line of credit outstanding	(186,000,000)
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due March 2030
Debt Instrument [Line Items]
Maximum borrowing capacity	200,000,000
Available unused credit	136,000,000
Port Arthur LNG | Port Arthur LNG Committed Line Of Credit Due March 2030 | Letters of Credit
Debt Instrument [Line Items]
Line of credit outstanding	(64,000,000)
Port Arthur LNG | Commercial Paper | Port Arthur LNG Committed Line Of Credit Due March 2030
Debt Instrument [Line Items]
Line of credit outstanding	0
Port Arthur LNG | Amounts Outstanding | Port Arthur LNG Committed Line Of Credit Due March 2030
Debt Instrument [Line Items]
Line of credit outstanding	$ 0

DEBT AND CREDIT FACILITIES - UN

DEBT AND CREDIT FACILITIES - UNCOMMITTED LINES OF CREDIT (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900
ECA LNG Phase 1 | Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate	1.54%
ECA LNG Phase 1 | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate	1.64%
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 100
Amount outstanding	$ 8
Line of Credit | ECA LNG Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate	0.10%

DEBT AND CREDIT FACILITIES - _3

DEBT AND CREDIT FACILITIES - UNCOMMITTED LETTERS OF CREDIT (Details) $ in Millions	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding	$ 497
Letters of Credit
Debt Instrument [Line Items]
Long-term debt outstanding	497
Letters of Credit | SDG&E
Debt Instrument [Line Items]
Long-term debt outstanding	26
Letters of Credit | SoCalGas
Debt Instrument [Line Items]
Long-term debt outstanding	20
Letters of Credit | Other Sempra
Debt Instrument [Line Items]
Long-term debt outstanding	$ 451

DEBT AND CREDIT FACILITIES - TE

DEBT AND CREDIT FACILITIES - TERM LOAN (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2024	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Short-Term Debt [Line Items]
Issuances of debt (maturities greater than 90 days)		$ 8,674	$ 7,669	$ 9,984
SoCalGas
Short-Term Debt [Line Items]
Issuances of debt (maturities greater than 90 days)		1,794	$ 997	$ 2,094
364-Day Term Loan, Due May 22,2025 | SoCalGas
Short-Term Debt [Line Items]
Variable percentage rate	0.80%
Credit adjustment spread	0.10%
364-Day Term Loan, Due May 22,2025 | SoCalGas | Secured Debt | Line of Credit
Short-Term Debt [Line Items]
Debt amount	$ 500	700
Term of contract (in years)	364 days
Proceeds from lines of credit		$ 700
Increase in term loan facility	$ 300

DEBT AND CREDIT FACILITIES - WE

DEBT AND CREDIT FACILITIES - WEIGHTED AVERAGE INTEREST RATES (Details)	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	5.03%	5.96%
SDG&E
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	4.76%	0%
SoCalGas
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	5.02%	5.44%

DEBT AND CREDIT FACILITIES - SC

DEBT AND CREDIT FACILITIES - SCHEDULE OF LONG-TERM DEBT INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Nov. 30, 2024	Mar. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Gross long-term debt	$ 16,590			$ 12,207
Long-term debt and finance leases	1,250			1,276
Finance lease obligations	1,315			1,340
Current portion of long-term debt and finance leases	(2,274)			(975)
Long-term debt and finance leases	31,558			27,759
SDG&E
Debt Instrument [Line Items]
Gross long-term debt	8,950			8,350
Long-term debt and finance leases	1,163			1,192
Long term debt and lease obligations, including current maturities	10,155			9,983
Finance lease obligations	1,205			1,233
Current portion of long-term debt and finance leases	(42)			(441)
Unamortized discount on long-term debt	(33)			(29)
Unamortized debt issuance costs	(62)			(60)
Total debt and lease obligations	10,018			9,453
Long-term debt and finance leases	$ 10,018			9,453
SDG&E | First Mortgage Bonds, 2.5% May 15, 2026
Debt Instrument [Line Items]
Stated percentage rate	2.50%
Gross long-term debt	$ 500			500
SDG&E | First Mortgage Bonds, 6% June 1, 2026
Debt Instrument [Line Items]
Stated percentage rate	6%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 4.95% August 15, 2028
Debt Instrument [Line Items]
Stated percentage rate	4.95%
Gross long-term debt	$ 600			600
SDG&E | First Mortgage Bonds, 1.7% October 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	1.70%
Gross long-term debt	$ 800			800
SDG&E | First Mortgage Bonds, 3% March 15, 2032
Debt Instrument [Line Items]
Stated percentage rate	3%
Gross long-term debt	$ 500			500
SDG&E | First Mortgage Bonds, 5.35% May 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 6.125% September 15, 2037
Debt Instrument [Line Items]
Stated percentage rate	6.125%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 6% June 1, 2039
Debt Instrument [Line Items]
Stated percentage rate	6%
Gross long-term debt	$ 300			300
SDG&E | First Mortgage Bonds, 5.35% May 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 4.5% August 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	4.50%
Gross long-term debt	$ 500			500
SDG&E | First Mortgage Bonds, 3.95% November 15, 2041
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 4.3% April 1, 2042
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 250			250
SDG&E | First Mortgage Bonds, 3.75% June 1, 2047
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 400			400
SDG&E | First Mortgage Bonds, 4.15% May 15, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.15%
Gross long-term debt	$ 400			400
SDG&E | First Mortgage Bonds, 4.1% June 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.10%
Gross long-term debt	$ 400			400
SDG&E | First Mortgage Bonds, 3.32% April 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.32%
Gross long-term debt	$ 400			400
SDG&E | First Mortgage Bonds, 2.95% August 15, 2051
Debt Instrument [Line Items]
Stated percentage rate	2.95%
Gross long-term debt	$ 750			750
SDG&E | First Mortgage Bonds, 3.7% March 15, 2052
Debt Instrument [Line Items]
Stated percentage rate	3.70%
Gross long-term debt	$ 500			500
SDG&E | First Mortgage Bonds, 5.35% April 1, 2053
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 800			800
SDG&E | First Mortgage Bonds, 5.55% April 5, 2054
Debt Instrument [Line Items]
Stated percentage rate	5.55%
Gross long-term debt	$ 600			$ 0
SDG&E | Other Long-Term Debt, February 18, 2024
Debt Instrument [Line Items]
Stated percentage rate				5.99%
Gross long-term debt	0			$ 400
SDG&E | Power purchase agreements
Debt Instrument [Line Items]
Long-term debt and finance leases	1,138			1,166
SDG&E | Other
Debt Instrument [Line Items]
Long-term debt and finance leases	67			67
SDG&E | Other Long-term Debt
Debt Instrument [Line Items]
Long term debt and lease obligations, including current maturities	1,205			1,633
SoCalGas
Debt Instrument [Line Items]
Gross long-term debt	6,650			6,050
Long-term debt and finance leases	87			84
Long term debt and lease obligations, including current maturities	7,469			6,866
Finance lease obligations	110			107
Finance lease obligations and other long term debt	819			816
Current portion of long-term debt and finance leases	(373)			(523)
Unamortized discount on long-term debt	(18)			(13)
Unamortized debt issuance costs	(47)			(42)
Total debt and lease obligations	7,031			6,288
Long-term debt and finance leases	$ 7,031			6,288
SoCalGas | First Mortgage Bonds, 3.15% September 15, 2024
Debt Instrument [Line Items]
Stated percentage rate	3.15%
Gross long-term debt	$ 0			500
SoCalGas | First Mortgage Bonds, 3.20% June 15, 2025
Debt Instrument [Line Items]
Stated percentage rate	3.20%
Gross long-term debt	$ 350			350
SoCalGas | First Mortgage Bonds, 2.60% June 15, 2026 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.60%
Gross long-term debt	$ 500			500
SoCalGas | First Mortgage Bonds, 2.55% February 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	2.55%
Gross long-term debt	$ 650			650
SoCalGas | First Mortgage Bonds, 5.20% June 1, 2023
Debt Instrument [Line Items]
Stated percentage rate	5.20%
Gross long-term debt	$ 500			500
SoCalGas | First Mortgage Bonds, 5.05% September 1, 2034
Debt Instrument [Line Items]
Stated percentage rate	5.05%
Gross long-term debt	$ 600			0
SoCalGas | First Mortgage Bonds, 5.75% November 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 250			250
SoCalGas | First Mortgage Bonds, 5.125% November 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.125%
Gross long-term debt	$ 300			300
SoCalGas | First Mortgage Bonds, 3.75% September 15, 2042
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 350			350
SoCalGas | First Mortgage Bonds, 4.45% March 15, 2044
Debt Instrument [Line Items]
Stated percentage rate	4.45%
Gross long-term debt	$ 250			250
SoCalGas | First Mortgage Bonds, 4.125% June 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.125%
Gross long-term debt	$ 400			400
SoCalGas | First Mortgage Bonds, 4.30% January 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 550			550
SoCalGas | First Mortgage Bonds, 3.95% February 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 350			350
SoCalGas | First Mortgage Bonds, 6.35% November 15, 2052
Debt Instrument [Line Items]
Stated percentage rate	6.35%
Gross long-term debt	$ 600			600
SoCalGas | First Mortgage Bonds, 5.75% June 1, 2053
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 500			500
SoCalGas | First Mortgage Bonds, 5.60% April 1, 2054
Debt Instrument [Line Items]
Stated percentage rate	5.60%
Gross long-term debt	$ 500			0
SoCalGas | Other Long-Term Debt, 1.875% Notes May 14, 2026
Debt Instrument [Line Items]
Stated percentage rate	1.875%
Gross long-term debt	$ 4			4
SoCalGas | Other Long-Term Debt, 2.95% Notes April 15, 2027
Debt Instrument [Line Items]
Stated percentage rate	2.95%
Gross long-term debt	$ 700			700
SoCalGas | Other Long-Term Debt, 5.67% Notes January 18, 2028
Debt Instrument [Line Items]
Stated percentage rate	5.67%
Gross long-term debt	$ 5			5
Other Sempra
Debt Instrument [Line Items]
Gross long-term debt	11,908			8,558
Current portion of long-term debt and finance leases	(1,859)			(11)
Unamortized discount on long-term debt	(78)			(66)
Unamortized debt issuance costs	(144)			(112)
Long-term debt and finance leases	$ 14,509			12,018
Other Sempra | Other Long-Term Debt, 3.30% Notes April 1, 2025
Debt Instrument [Line Items]
Stated percentage rate	3.30%
Gross long-term debt	$ 750			750
Other Sempra | Other Long-Term Debt, 5.40% Notes August 1, 2026
Debt Instrument [Line Items]
Stated percentage rate	5.40%
Gross long-term debt	$ 550			550
Other Sempra | Other Long-Term Debt, 3.25% Notes June 15, 2027
Debt Instrument [Line Items]
Stated percentage rate	3.25%
Gross long-term debt	$ 750			750
Other Sempra | Other Long-Term Debt, 3.40% Notes February 1, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.40%
Gross long-term debt	$ 1,000			1,000
Other Sempra | Other Long-Term Debt, 3.70% Notes April 1, 2029
Debt Instrument [Line Items]
Stated percentage rate	3.70%
Gross long-term debt	$ 500			500
Other Sempra | Other Long-Term Debt, 5.50% Notes August 1, 2033
Debt Instrument [Line Items]
Stated percentage rate	5.50%
Gross long-term debt	$ 700			700
Other Sempra | Other Long-Term Debt, 3.80% Notes February 1, 2038
Debt Instrument [Line Items]
Stated percentage rate	3.80%
Gross long-term debt	$ 1,000			1,000
Other Sempra | Other Long-Term Debt, 6.00% Notes October 15, 2039
Debt Instrument [Line Items]
Stated percentage rate	6%
Gross long-term debt	$ 750			750
Other Sempra | Other Long-Term Debt, 4.00% Notes February 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4%
Gross long-term debt	$ 800			800
Other Sempra | Other Long-Term Debt, 4.125% Junior Subordinated Notes April 1, 2052
Debt Instrument [Line Items]
Stated percentage rate	4.125%		4.125%
Gross long-term debt	$ 1,000			1,000
Other Sempra | Other Long-Term Debt, 6.40% Junior Subordinated Notes October 1, 2054
Debt Instrument [Line Items]
Stated percentage rate	6.40%
Gross long-term debt	$ 1,250			0
Other Sempra | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054
Debt Instrument [Line Items]
Stated percentage rate	6.875%
Gross long-term debt	$ 600			0
Other Sempra | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054, Two
Debt Instrument [Line Items]
Stated percentage rate	6.875%
Gross long-term debt	$ 500			0
Other Sempra | Other Long-Term Debt, 6.55% Junior Subordinated Notes April 1, 2055
Debt Instrument [Line Items]
Stated percentage rate	6.55%	6.55%
Gross long-term debt	$ 600			0
Other Sempra | Other Long-Term Debt, 6.625% Junior Subordinated Notes April 1, 2055
Debt Instrument [Line Items]
Stated percentage rate	6.625%	6.625%
Gross long-term debt	$ 400			0
Other Sempra | Other Long-Term Debt, 5.75% Junior Subordinated Notes July 1, 2079
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 758			758
Sempra Infrastructure
Debt Instrument [Line Items]
Gross long-term debt	$ 4,682			$ 3,649
Sempra Infrastructure | Loan at variable rates (weighted-average rate of 7.29% and 8.31% at December 31, 2024 and 2023, respectively) December 9, 2025
Debt Instrument [Line Items]
Stated percentage rate	7.29%			8.31%
Gross long-term debt	$ 1,063			$ 832
Sempra Infrastructure | 3.75% Notes January 14, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 300			300
Sempra Infrastructure | Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets(1)
Debt Instrument [Line Items]
Gross long-term debt	$ 1,090			258
Sempra Infrastructure | 3.25% Notes January 15, 2032
Debt Instrument [Line Items]
Stated percentage rate	3.25%
Gross long-term debt	$ 400			$ 400
Sempra Infrastructure | Other Long-Term Debt, Loan At Variable Rates (7.37% Weighted-Average Rate) [Member]
Debt Instrument [Line Items]
Weighted average rate				7.37%
Long-term debt subject to variable rate				$ 58
Sempra Infrastructure | Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034
Debt Instrument [Line Items]
Fixed interest rate after floating to fixed interest rate swaps	4.03%
Gross long-term debt	$ 90			96
Sempra Infrastructure | Loan at variable rates (4.03% after floating-to-fixed rate swap effective 2019) payable June 15, 2022 through November 19, 2034
Debt Instrument [Line Items]
Fixed interest rate after floating to fixed interest rate swaps	4.03%
Gross long-term debt	$ 90			96
Sempra Infrastructure | Other Long-Term Debt, Loan at Variable Rates (2.38% After Floating-To-Fixed Rate Swap Effective 2020) Payable June 15, 2022 Through November 19, 2034
Debt Instrument [Line Items]
Fixed interest rate after floating to fixed interest rate swaps	2.38%
Gross long-term debt	$ 90			96
Sempra Infrastructure | Other Long-Term Debt, 2.9% Loan payable June 15, 2022 through November 19, 2034
Debt Instrument [Line Items]
Fixed interest rate after floating to fixed interest rate swaps	2.90%
Gross long-term debt	$ 219			231
Sempra Infrastructure | Other Long-Term Debt, 4.875% Notes January 14, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.875%
Gross long-term debt	$ 540			540
Sempra Infrastructure | Other Long-Term Debt, 4.75% Notes January 15, 2051
Debt Instrument [Line Items]
Stated percentage rate	4.75%
Gross long-term debt	$ 800			$ 800

DEBT AND CREDIT FACILITIES - _4

DEBT AND CREDIT FACILITIES - SCHEDULE OF MATURITIES OF LONG-TERM DEBT (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Schedule Of Long Term Debt Maturities [Line Items]
2025	$ 2,212
2026	1,853
2027	1,499
2028	1,963
2029	584
Thereafter	24,788
Total	32,899
Various long-term obligations	16,200
Gross long-term debt	16,590	$ 12,207
SDG&E
Schedule Of Long Term Debt Maturities [Line Items]
2025	0
2026	750
2027	0
2028	600
2029	0
Thereafter	7,600
Total	8,950
Gross long-term debt	8,950	8,350
SoCalGas
Schedule Of Long Term Debt Maturities [Line Items]
2025	350
2026	504
2027	700
2028	5
2029	0
Thereafter	5,800
Total	7,359
Various long-term obligations	709
Gross long-term debt	6,650	6,050
Other Sempra
Schedule Of Long Term Debt Maturities [Line Items]
2025	1,862
2026	599
2027	799
2028	1,358
2029	584
Thereafter	11,388
Total	16,590
Gross long-term debt	11,908	8,558
Sempra Infrastructure
Schedule Of Long Term Debt Maturities [Line Items]
Gross long-term debt	4,682	3,649
Sempra Infrastructure | Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets(1)
Schedule Of Long Term Debt Maturities [Line Items]
Gross long-term debt	$ 1,090	$ 200

DEBT AND CREDIT FACILITIES - _5

DEBT AND CREDIT FACILITIES - SCHEDULE OF CALLABLE LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2024 USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Not subject to make-whole provisions	$ 6,691
Subject to make-whole provisions	26,203
SDG&E
Schedule Of Callable Long-term Debt [Line Items]
Not subject to make-whole provisions	0
Subject to make-whole provisions	8,950
SoCalGas
Schedule Of Callable Long-term Debt [Line Items]
Not subject to make-whole provisions	4
Subject to make-whole provisions	7,350
Other Sempra
Schedule Of Callable Long-term Debt [Line Items]
Not subject to make-whole provisions	6,687
Subject to make-whole provisions	$ 9,903

DEBT AND CREDIT FACILITIES - FI

DEBT AND CREDIT FACILITIES - FIRST MORTGAGE BONDS (Details) - USD ($) $ in Millions	1 Months Ended
	Aug. 31, 2024	Mar. 31, 2024	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Gross long-term debt			$ 16,590	$ 12,207
SDG&E
Debt Instrument [Line Items]
First mortgage bonds available for future issuance			8,800
Gross long-term debt			8,950	8,350
SDG&E | First Mortgage Bonds, 5.55% April 5, 2054
Debt Instrument [Line Items]
Gross long-term debt			$ 600	0
Stated percentage rate			5.55%
SDG&E | First Mortgage Bonds, 5.55%, Due April 15, 2054 | Secured Debt
Debt Instrument [Line Items]
Proceeds from issuance of debt		$ 587
Underwriting discounts and debt issuance costs		13
SoCalGas
Debt Instrument [Line Items]
First mortgage bonds available for future issuance			$ 1,600
Gross long-term debt			6,650	6,050
SoCalGas | First Mortgage Bonds, 5.60% April 1, 2054
Debt Instrument [Line Items]
Gross long-term debt			$ 500	0
Stated percentage rate			5.60%
SoCalGas | Five Point Six Percent First Mortgage Bonds, Due April 1, 2054 | Secured Debt
Debt Instrument [Line Items]
Proceeds from issuance of debt		491
Underwriting discounts and debt issuance costs		$ 9
SoCalGas | First Mortgage Bonds, 5.05% September 1, 2034
Debt Instrument [Line Items]
Gross long-term debt			$ 600	$ 0
Stated percentage rate			5.05%
SoCalGas | First Mortgage Bonds, 5.05% September 1, 2034 | Secured Debt
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 592
Underwriting discounts and debt issuance costs	$ 8

DEBT AND CREDIT FACILITIES - OT

DEBT AND CREDIT FACILITIES - OTHER LONG-TERM DEBT (Details) $ in Millions	1 Months Ended				12 Months Ended
	Nov. 30, 2024 USD ($)	Sep. 30, 2024 USD ($)	May 31, 2024 USD ($)	Mar. 31, 2024 USD ($)	Dec. 31, 2024 USD ($) business_day
Debt Instrument [Line Items]
Various long-term obligations					$ 16,200
Not subject to make-whole provisions					6,691
Subject to make-whole provisions					26,203
Other Sempra
Debt Instrument [Line Items]
Not subject to make-whole provisions					6,687
Subject to make-whole provisions					9,903
Variable percentage rate	2.354%	2.632%
SoCalGas
Debt Instrument [Line Items]
Various long-term obligations					709
Not subject to make-whole provisions					4
Subject to make-whole provisions					$ 7,350
Five Point Six Percent First Mortgage Bonds, Due April 1, 2054 | Other Sempra
Debt Instrument [Line Items]
Number of days before interest rate period | business_day					2
Debt instrument, interest rate, period (in years)					5 years
Five Point Six Percent First Mortgage Bonds, Due April 1, 2054 | SoCalGas | Secured Debt
Debt Instrument [Line Items]
Proceeds from issuance of debt				$ 491
Underwriting discounts and debt issuance costs				9
6.875% Junior Subordinated Notes, Due October 1, 2054 | Other Sempra
Debt Instrument [Line Items]
Debt amount			$ 500
Proceeds from issuance of debt			489
Underwriting discounts and debt issuance costs			11
Accrued interest			$ 7
6.40% Junior Subordinated Notes, Due October 1, 2054
Debt Instrument [Line Items]
Stated percentage rate		6.40%
6.40% Junior Subordinated Notes, Due October 1, 2054 | Other Sempra
Debt Instrument [Line Items]
Debt amount		$ 1,250
Proceeds from issuance of debt		1,235
Underwriting discounts and debt issuance costs		$ 15
Other Long-Term Debt, 6.625% Junior Subordinated Notes April 1, 2055 | Other Sempra
Debt Instrument [Line Items]
Debt amount	$ 400
Stated percentage rate	6.625%				6.625%
Proceeds from issuance of debt	$ 395
Underwriting discounts and debt issuance costs	5
Other Long-Term Debt, 6.55% Junior Subordinated Notes April 1, 2055 | Other Sempra
Debt Instrument [Line Items]
Debt amount	$ 600
Stated percentage rate	6.55%				6.55%
Proceeds from issuance of debt	$ 593
Underwriting discounts and debt issuance costs	$ 7
Variable percentage rate	2.138%
Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054 | Other Sempra
Debt Instrument [Line Items]
Debt amount				600
Stated percentage rate					6.875%
Proceeds from issuance of debt				593
Underwriting discounts and debt issuance costs				$ 7
Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054 | Other Sempra | Period one
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)			100%		100%
Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054 | Other Sempra | Period two
Debt Instrument [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)			102%	102%
6.875% Junior Subordinated Notes, Issued In March and May 2024 | Other Sempra
Debt Instrument [Line Items]
Variable percentage rate			2.789%
Loan at variable rates (includes $1,090 and $200 at December 31, 2024 and 2023, respectively, (5.329% after floating-to-fixed rate swaps effective 2023) and $58 at December 31, 2023 (weighted-average rate of 7.37% at December 31, 2023)) March 20, 2030, collateralized by plant assets(1) | Sempra Infrastructure
Debt Instrument [Line Items]
Fixed percentage interest rate					5.329%

DEBT AND CREDIT FACILITIES - EC

DEBT AND CREDIT FACILITIES - ECA LNG PHASE 1 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) bank	Dec. 31, 2023 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 9,900
Gross long-term debt	16,590	$ 12,207
Sempra Infrastructure
Debt Instrument [Line Items]
Gross long-term debt	$ 4,682	3,649
IEnova | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity	83.40%
Subsidiary of TOTAL SE | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity	16.60%
Loan Agreement To Finance Natural Gas Liquefaction Export Facility | Sempra Infrastructure
Debt Instrument [Line Items]
Term of contract (in years)	5 years
Number of banks in syndicate | bank	7
Maximum borrowing capacity	$ 1,300
Gross long-term debt	$ 1,100	$ 832
Weighted average rate	7.29%	8.31%

DEBT AND CREDIT FACILITIES - Po

DEBT AND CREDIT FACILITIES - Port Arthur LNG (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Apr. 30, 2025	Jan. 31, 2025	Dec. 31, 2023
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 9,900,000,000
Gross long-term debt	16,590,000,000			$ 12,207,000,000
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project | Port Arthur LNG
Debt Instrument [Line Items]
Gross long-term debt	$ 1,100,000,000			$ 258,000,000
Weighted average rate	5.33%			5.81%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project | Domestic Line of Credit | Port Arthur LNG
Debt Instrument [Line Items]
Term of contract (in years)	7 years
Maximum borrowing capacity	$ 6,800,000,000
Senior Secured Notes Issued Jan 2025 | Senior Notes | Port Arthur LNG | Subsequent Event
Debt Instrument [Line Items]
Debt amount			$ 750,000,000
Stated percentage rate			6.27%
Senior Secured Notes Issued Apr 2025 | Senior Notes | Port Arthur LNG | Forecast
Debt Instrument [Line Items]
Debt amount		$ 250,000,000
Stated percentage rate		6.32%

INCOME TAXES - RECONCILIATION T

INCOME TAXES - RECONCILIATION TO EFFECTIVE TAX RATE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 219	$ 490	$ 556
Income before income taxes and equity earnings	2,110	2,627	1,343
Equity earnings	603	633	666
Pretax income	$ 2,713	$ 3,260	$ 2,009
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21%	21%	21%
Foreign exchange and inflation effects	(14.00%)	9%	9%
Utility depreciation	4%	3%	4%
Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate	1%	1%	3%
State income taxes, net of federal income tax benefit	1%	1%	1%
Outside basis differences	0%	0%	6%
Valuation allowances	14%	0%	(2.00%)
Utility self-developed software expenditures	(1.00%)	(1.00%)	0%
Allowance for equity funds used during construction	(1.00%)	(1.00%)	(1.00%)
Amortization of excess deferred income taxes	(1.00%)	(1.00%)	(2.00%)
Remeasurement of deferred taxes	0%	(1.00%)	(3.00%)
Resolution of prior years’ income tax items	(2.00%)	(2.00%)	(2.00%)
Noncontrolling interests	(3.00%)	(3.00%)	0%
Tax credits	(1.00%)	(5.00%)	(1.00%)
Utility repairs expenditures	(8.00%)	(6.00%)	(5.00%)
Other, net	(2.00%)	0%	0%
Effective income tax rate	8%	15%	28%
SDG&E
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 153	$ (26)	$ 182
Income before income taxes and equity earnings	1,044	910	1,097
Pretax income	$ 1,044	$ 910	$ 1,097
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21%	21%	21%
Utility depreciation	5%	5%	3%
State income taxes, net of federal income tax benefit	3%	2%	4%
Utility self-developed software expenditures	(1.00%)	(1.00%)	0%
Allowance for equity funds used during construction	(1.00%)	(2.00%)	(2.00%)
Amortization of excess deferred income taxes	(1.00%)	(2.00%)	(2.00%)
Resolution of prior years’ income tax items	(1.00%)	(1.00%)	(2.00%)
Tax credits	(1.00%)	(16.00%)	0%
Utility repairs expenditures	(9.00%)	(8.00%)	(5.00%)
Other, net	0%	(1.00%)	0%
Effective income tax rate	15%	(3.00%)	17%
SoCalGas
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 31	$ (5)	$ 138
Income before income taxes and equity earnings	987	807	738
Pretax income	$ 987	$ 807	$ 738
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21%	21%	21%
Utility depreciation	5%	5%	5%
State income taxes, net of federal income tax benefit	(1.00%)	(2.00%)	2%
Nondeductible expenditures	0%	0%	2%
Utility self-developed software expenditures	(2.00%)	(2.00%)	0%
Allowance for equity funds used during construction	(2.00%)	(1.00%)	(2.00%)
Amortization of excess deferred income taxes	(1.00%)	(2.00%)	(2.00%)
Resolution of prior years’ income tax items	(3.00%)	(6.00%)	0%
Utility repairs expenditures	(14.00%)	(14.00%)	(6.00%)
Other, net	0%	0%	(1.00%)
Effective income tax rate	3%	(1.00%)	19%

INCOME TAXES - COMPONENTS OF IN

INCOME TAXES - COMPONENTS OF INCOME TAX EXPENSE (BENEFIT) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S.	$ 2,354	$ 2,678	$ 1,449
Non-U.S.	359	582	560
Pretax income	2,713	3,260	2,009
Current:
U.S. federal	73	102	0
U.S. state	(4)	3	(1)
Non-U.S.	179	208	165
Total	248	313	164
Deferred:
U.S. federal	366	(56)	248
U.S. state	28	18	50
Non-U.S.	(422)	225	94
Total	(28)	187	392
Deferred investment tax credits	(1)	(10)	0
Total income tax expense	219	490	556
Oncor Holdings
Deferred:
Total	9	72
SDG&E
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	1,044	910	1,097
Current:
U.S. federal	(16)	(156)	76
U.S. state	0	(5)	13
Total	(16)	(161)	89
Deferred:
U.S. federal	129	111	54
U.S. state	41	35	38
Total	170	146	92
Deferred investment tax credits	(1)	(11)	1
Total income tax expense	153	(26)	182
SoCalGas
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	987	807	738
Current:
U.S. federal	3	(6)	(5)
U.S. state	0	(11)	(3)
Total	3	(17)	(8)
Deferred:
U.S. federal	45	22	125
U.S. state	(16)	(11)	22
Total	29	11	147
Deferred investment tax credits	(1)	1	(1)
Total income tax expense	$ 31	$ (5)	$ 138

INCOME TAXES - DEFERRED INCOME

INCOME TAXES - DEFERRED INCOME TAXES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Deferred income tax liabilities:
Differences in financial and tax bases of utility plant and other assets	$ 7,164	$ 6,875
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	79	55
Regulatory balancing accounts	850	727
Right-of-use assets – operating leases	325	211
Property taxes	74	68
Postretirement benefits	150	47
Other deferred income tax liabilities	94	68
Total deferred income tax liabilities	8,736	8,051
Deferred income tax assets:
Tax credits	1,485	1,468
Net operating losses	1,105	982
Compensation-related items	225	157
Operating lease liabilities	301	179
Other deferred income tax assets	219	96
Bad debt allowance	151	144
Accrued expenses not yet deductible	80	89
Deferred income tax assets before valuation allowances	3,566	3,115
Less: valuation allowances	503	189
Total deferred income tax assets	3,063	2,926
Net deferred income tax liability	5,673	5,125
Deferred income taxes assets, noncurrent	172	129
Deferred income tax liabilities, noncurrent	5,845	5,254
SDG&E
Deferred income tax liabilities:
Differences in financial and tax bases of utility plant and other assets	2,805	2,641
Regulatory balancing accounts	545	418
Right-of-use assets – operating leases	222	103
Property taxes	47	43
Postretirement benefits	0	0
Other deferred income tax liabilities	0	0
Total deferred income tax liabilities	3,619	3,205
Deferred income tax assets:
Tax credits	8	7
Net operating losses	122	146
Compensation-related items	8	9
Operating lease liabilities	222	103
Other deferred income tax assets	9	19
Bad debt allowance	29	37
Accrued expenses not yet deductible	10	11
Total deferred income tax assets	408	332
Net deferred income tax liability	3,211	2,873
Deferred income tax liabilities, noncurrent	3,211	2,873
SoCalGas
Deferred income tax liabilities:
Differences in financial and tax bases of utility plant and other assets	2,594	2,272
Regulatory balancing accounts	306	309
Right-of-use assets – operating leases	5	8
Property taxes	27	25
Postretirement benefits	124	71
Other deferred income tax liabilities	2	4
Total deferred income tax liabilities	3,058	2,689
Deferred income tax assets:
Tax credits	2	7
Net operating losses	874	890
Compensation-related items	26	31
Operating lease liabilities	5	8
Other deferred income tax assets	20	25
Bad debt allowance	72	86
Accrued expenses not yet deductible	54	56
Total deferred income tax assets	1,053	1,103
Net deferred income tax liability	2,005	1,586
Deferred income tax liabilities, noncurrent	$ 2,005	$ 1,586

INCOME TAXES - NET OPERATING LO

INCOME TAXES - NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Operating Loss Carryforwards [Line Items]
Valuation allowances	$ 503	$ 189
U.S. federal
Operating Loss Carryforwards [Line Items]
NOLs	3,091
Valuation allowances	406	108
U.S. federal | SoCalGas
Operating Loss Carryforwards [Line Items]
NOLs	2,857
U.S. federal | SDG&E
Operating Loss Carryforwards [Line Items]
NOLs	279
U.S. federal | General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	126
U.S. federal | General business tax credits | SDG&E
Operating Loss Carryforwards [Line Items]
Tax credits	1
U.S. federal | Corporate alternative minimum tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	676
U.S. federal | Foreign tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	706
U.S. state
Operating Loss Carryforwards [Line Items]
NOLs	5,912
Valuation allowances	47	51
U.S. state | SoCalGas
Operating Loss Carryforwards [Line Items]
NOLs	3,917
U.S. state | SDG&E
Operating Loss Carryforwards [Line Items]
NOLs	909
U.S. state | General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	24
Non-U.S.
Operating Loss Carryforwards [Line Items]
NOLs	782
Valuation allowances	50	$ 30
Non-U.S. | General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	$ 5

INCOME TAXES - UNRECOGNIZED TAX

INCOME TAXES - UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Reconciliation of Unrecognized Tax Benefits
Beginning balance	$ 492	$ 278	$ 304
Increase in prior period tax positions	40	308	16
Decrease in prior period tax positions	(8)	(63)	(2)
Decrease in current period tax positions	0	(21)	0
Settlements with tax authorities	(15)	(16)	(43)
Expiration of statutes of limitations	0	0	(1)
Increase in current period tax positions	39	6	4
Ending balance	548	492	278
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(229)	(224)	(117)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	1	1	38
SDG&E
Reconciliation of Unrecognized Tax Benefits
Beginning balance	14	14	14
Increase in prior period tax positions	0	2	0
Settlements with tax authorities	0	(2)	0
Ending balance	14	14	14
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(11)	(11)	(11)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	1	1	1
SoCalGas
Reconciliation of Unrecognized Tax Benefits
Beginning balance	29	77	72
Increase in prior period tax positions	0	1	1
Decrease in prior period tax positions	0	(47)	0
Settlements with tax authorities	0	(2)	0
Increase in current period tax positions	0	0	4
Ending balance	29	29	77
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(29)	(29)	(67)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	$ 0	$ 0	$ 37

INCOME TAXES - NARRATIVE (Detai

INCOME TAXES - NARRATIVE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense	$ 330
Foreign undistributed earnings	3,100
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested	100
Foreign earnings repatriated	100	$ 108
Accrual for interest and penalties	15	15
Interest and penalties expense		2
Income tax expense (benefit)	219	490	$ 556
SoCalGas
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense (benefit)	31	(5)	138
SoCalGas | Change in Accounting Method Accounted for as Change in Estimate
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense (benefit)		(97)
SDG&E
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense (benefit)	153	(26)	$ 182
SDG&E | Change in Accounting Method Accounted for as Change in Estimate
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense (benefit)		(34)
Cumulative Effect, Period of Adoption, Adjustment | SoCalGas
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense (benefit)		$ (43)
Non-U.S.
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested	700
Income tax expense	$ 120

INCOME TAXES - CHANGES IN UNREC

INCOME TAXES - CHANGES IN UNRECOGNIZED TAX BENEFITS (Details) - Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ 15	$ 242	$ 8
SDG&E
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	6	6	6
SoCalGas
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ 2	$ 2	$ 2

EMPLOYEE BENEFIT PLANS - DEDICA

EMPLOYEE BENEFIT PLANS - DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Retirement Benefits [Abstract]
Dedicated assets in support of certain benefit plans	$ 585	$ 549

EMPLOYEE BENEFIT PLANS - PENSIO

EMPLOYEE BENEFIT PLANS - PENSION AND PBOP PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Oncor Electric Delivery Company LLC | Other Postretirement Benefits Plan | Sempra Texas Utilities
Defined Benefit Plan Disclosure [Line Items]
Gain (loss) arising during the period	$ (34)	$ (38)

EMPLOYEE BENEFIT PLANS - PROJEC

EMPLOYEE BENEFIT PLANS - PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	$ 3,107	$ 2,806
Service cost	132	109	$ 146
Interest cost	166	157	118
Contributions from plan participants	0	0
Actuarial (gain) loss	(100)	190
Plan amendments	2	4
Benefit payments	(81)	(83)
Settlements	(87)	(76)
Obligation at December 31	3,139	3,107	2,806
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	2,664	2,390
Actual return on plan assets	196	218
Employer contributions	243	215
Contributions from plan participants	0	0
Benefit payments	(81)	(83)
Settlements	(87)	(76)
Fair value of plan assets at December 31	2,935	2,664	2,390
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(204)	(443)
Net recorded (liability) asset at December 31	(204)	(443)
Accumulated benefit obligation	2,900	2,865
Pension Plan | SDG&E
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	807	714
Service cost	39	32	37
Interest cost	43	40	26
Contributions from plan participants	0	0
Actuarial (gain) loss	(28)	69
Benefit payments	(16)	(17)
Settlements	(23)	(31)
Obligation at December 31	822	807	714
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	726	670
Actual return on plan assets	63	52
Employer contributions	37	52
Contributions from plan participants	0	0
Benefit payments	(16)	(17)
Settlements	(23)	(31)
Fair value of plan assets at December 31	787	726	670
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(35)	(81)
Net recorded (liability) asset at December 31	(35)	(81)
Accumulated benefit obligation	781	769
Pension Plan | SoCalGas
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	1,977	1,814
Service cost	79	65	96
Interest cost	105	101	81
Contributions from plan participants	0	0
Actuarial (gain) loss	(70)	90
Plan amendments	2	0
Benefit payments	(56)	(58)
Settlements	(38)	(35)
Obligation at December 31	1,999	1,977	1,814
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,744	1,535
Actual return on plan assets	115	151
Employer contributions	172	151
Contributions from plan participants	0	0
Benefit payments	(56)	(58)
Settlements	(38)	(35)
Fair value of plan assets at December 31	1,937	1,744	1,535
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(62)	(233)
Net recorded (liability) asset at December 31	(62)	(233)
Accumulated benefit obligation	1,824	1,799
Other Postretirement Benefits Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	693	663
Service cost	15	13	23
Interest cost	36	37	28
Contributions from plan participants	23	23
Actuarial (gain) loss	(11)	28
Plan amendments	0	0
Benefit payments	(69)	(71)
Settlements	0	0
Obligation at December 31	687	693	663
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,169	1,096
Actual return on plan assets	57	117
Employer contributions	5	4
Contributions from plan participants	23	23
Benefit payments	(69)	(71)
Settlements	0	0
Fair value of plan assets at December 31	1,185	1,169	1,096
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	498	476
Net recorded (liability) asset at December 31	498	476
Other Postretirement Benefits Plan | SDG&E
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	140	134
Service cost	3	3	5
Interest cost	7	8	6
Contributions from plan participants	8	8
Actuarial (gain) loss	(6)	7
Benefit payments	(18)	(20)
Settlements	0	0
Obligation at December 31	134	140	134
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	150	147
Actual return on plan assets	5	14
Employer contributions	0	1
Contributions from plan participants	8	8
Benefit payments	(18)	(20)
Settlements	0	0
Fair value of plan assets at December 31	145	150	147
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	11	10
Net recorded (liability) asset at December 31	11	10
Other Postretirement Benefits Plan | SoCalGas
CHANGE IN PROJECTED BENEFIT OBLIGATION
Obligation at January 1	521	497
Service cost	11	9	17
Interest cost	27	28	21
Contributions from plan participants	14	14
Actuarial (gain) loss	(4)	21
Plan amendments	0	0
Benefit payments	(47)	(48)
Settlements	0	0
Obligation at December 31	522	521	497
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	990	923
Actual return on plan assets	50	100
Employer contributions	1	1
Contributions from plan participants	14	14
Benefit payments	(47)	(48)
Settlements	0	0
Fair value of plan assets at December 31	1,008	990	$ 923
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	486	469
Net recorded (liability) asset at December 31	$ 486	$ 469

EMPLOYEE BENEFIT PLANS - PENS_2

EMPLOYEE BENEFIT PLANS - PENSION AND PBOP OBLIGATIONS, NET OF PLAN ASSETS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]
Noncurrent liabilities	$ (168)	$ (407)
SDG&E
Defined Benefit Plan Disclosure [Line Items]
Noncurrent liabilities	(28)	(79)
SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Noncurrent liabilities	(45)	(231)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	6	0
Current liabilities	(50)	(44)
Noncurrent liabilities	(160)	(399)
Net recorded (liability) asset at December 31	(204)	(443)
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(7)	(2)
Noncurrent liabilities	(28)	(79)
Net recorded (liability) asset at December 31	(35)	(81)
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	0	0
Current liabilities	(17)	(2)
Noncurrent liabilities	(45)	(231)
Net recorded (liability) asset at December 31	(62)	(233)
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	507	485
Current liabilities	(1)	(1)
Noncurrent liabilities	(8)	(8)
Net recorded (liability) asset at December 31	498	476
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	11	10
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset at December 31	11	10
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Noncurrent assets	486	469
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset at December 31	$ 486	$ 469

EMPLOYEE BENEFIT PLANS - AMOUNT

EMPLOYEE BENEFIT PLANS - AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (loss) gain	$ (120)	$ (124)
Prior service cost	(9)	(6)
Total	(129)	(130)
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (loss) gain	(12)	(8)
Total	(12)	(8)
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (loss) gain	(14)	(10)
Prior service cost	(3)	(2)
Total	(17)	(12)
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (loss) gain	14	13
Prior service cost	0	0
Total	$ 14	$ 13

EMPLOYEE BENEFIT PLANS - OBLIGA

EMPLOYEE BENEFIT PLANS - OBLIGATIONS OF FUNDED AND UNFUNDED PENSION AND PBOP PLANS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 2,900	$ 2,865
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	781	769
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	1,824	1,799
Funded Plan | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	2,752	2,925
Accumulated benefit obligation	2,542	2,712
Fair value of plan assets	2,724	2,664
Funded Plan | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	793	781
Accumulated benefit obligation	755	746
Fair value of plan assets	787	726
Funded Plan | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	1,959	1,944
Accumulated benefit obligation	1,787	1,771
Fair value of plan assets	1,937	1,744
Unfunded Plan | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	183	182
Accumulated benefit obligation	159	153
Unfunded Plan | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	29	26
Accumulated benefit obligation	26	23
Unfunded Plan | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	40	33
Accumulated benefit obligation	37	28
Unfunded Plan | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 9	$ 9

EMPLOYEE BENEFIT PLANS - NET PE

EMPLOYEE BENEFIT PLANS - NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
NET PERIODIC BENEFIT COST
Service cost	$ 132	$ 109	$ 146
Interest cost	166	157	118
Expected return on plan assets	(178)	(169)	(183)
Prior service cost (credit)	5	5	10
Actuarial loss (gain)	14	10	25
Settlement charges	9	0	28
Net periodic benefit cost (credit)	148	112	144
Regulatory adjustment	100	117	84
Total expense (income) recognized	248	229	228
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net (gain) loss	(2)	42	12
Prior service cost	3	4	0
Amortization of actuarial (loss) gain	(7)	(5)	(8)
Amortization of prior service cost	(3)	(2)	(4)
Settlements	(9)	0	0
Total recognized in OCI	(18)	39	0
Total recognized in net periodic benefit cost and OCI	230	268	228
Pension Plan | SDG&E
NET PERIODIC BENEFIT COST
Service cost	39	32	37
Interest cost	43	40	26
Expected return on plan assets	(45)	(39)	(46)
Prior service cost (credit)	1	1	1
Actuarial loss (gain)	8	4	1
Settlement charges	0	0	14
Net periodic benefit cost (credit)	46	38	33
Regulatory adjustment	(8)	15	20
Total expense (income) recognized	38	53	53
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net (gain) loss	4	3	(3)
Amortization of actuarial (loss) gain	(1)	0	(1)
Amortization of prior service cost	0	(1)	0
Total recognized in OCI	3	2	(4)
Total recognized in net periodic benefit cost and OCI	41	55	49
Pension Plan | SoCalGas
NET PERIODIC BENEFIT COST
Service cost	79	65	96
Interest cost	105	101	81
Expected return on plan assets	(121)	(119)	(126)
Prior service cost (credit)	4	4	8
Actuarial loss (gain)	1	1	18
Settlement charges	0	0	14
Net periodic benefit cost (credit)	68	52	91
Regulatory adjustment	108	102	64
Total expense (income) recognized	176	154	155
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net (gain) loss	4	2	(5)
Prior service cost	2	0	0
Amortization of actuarial (loss) gain	(1)	(1)	(2)
Amortization of prior service cost	(1)	(1)	(1)
Total recognized in OCI	4	0	(8)
Total recognized in net periodic benefit cost and OCI	180	154	147
Other Postretirement Benefits Plan
NET PERIODIC BENEFIT COST
Service cost	15	13	23
Interest cost	36	37	28
Expected return on plan assets	(70)	(69)	(64)
Prior service cost (credit)	(2)	(2)	(2)
Actuarial loss (gain)	(17)	(23)	(15)
Settlement charges	0	0	0
Net periodic benefit cost (credit)	(38)	(44)	(30)
Regulatory adjustment	38	43	30
Total expense (income) recognized	0	(1)	0
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net (gain) loss	(1)	(2)	(4)
Prior service cost	0	0	0
Amortization of actuarial (loss) gain	1	2	1
Amortization of prior service cost	0	0	0
Settlements	0	0	0
Total recognized in OCI	0	0	(3)
Total recognized in net periodic benefit cost and OCI	0	(1)	(3)
Other Postretirement Benefits Plan | SDG&E
NET PERIODIC BENEFIT COST
Service cost	3	3	5
Interest cost	7	8	6
Expected return on plan assets	(9)	(8)	(10)
Prior service cost (credit)	0	0	0
Actuarial loss (gain)	(1)	(2)	(2)
Settlement charges	0	0	0
Net periodic benefit cost (credit)	0	1	(1)
Regulatory adjustment	0	0	1
Total expense (income) recognized	0	1	0
Other Postretirement Benefits Plan | SoCalGas
NET PERIODIC BENEFIT COST
Service cost	11	9	17
Interest cost	27	28	21
Expected return on plan assets	(59)	(59)	(53)
Prior service cost (credit)	(3)	(2)	(2)
Actuarial loss (gain)	(14)	(19)	(12)
Settlement charges	0	0	0
Net periodic benefit cost (credit)	(38)	(43)	(29)
Regulatory adjustment	38	43	29
Total expense (income) recognized	$ 0	$ 0	$ 0

EMPLOYEE BENEFIT PLANS - WEIGHT

EMPLOYEE BENEFIT PLANS - WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION (Details)	Dec. 31, 2024	Dec. 31, 2023
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.74%	5.31%
Interest crediting rate	4.54%	4.66%
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.75%	5.30%
Interest crediting rate	4.54%	4.66%
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.70%	5.25%
Interest crediting rate	4.54%	4.66%
Pension Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Pension Plan | Minimum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%
Pension Plan | Minimum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Pension Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Pension Plan | Maximum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Pension Plan | Maximum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.75%	5.34%
Interest crediting rate	4.54%	4.66%
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.75%	5.30%
Interest crediting rate	4.54%	4.66%
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.75%	5.35%
Interest crediting rate	4.54%	4.66%
Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Other Postretirement Benefits Plan | Minimum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%
Other Postretirement Benefits Plan | Minimum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Other Postretirement Benefits Plan | Maximum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Other Postretirement Benefits Plan | Maximum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%

EMPLOYEE BENEFIT PLANS - WEIG_2

EMPLOYEE BENEFIT PLANS - WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST (Details)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.31%	5.63%	3.04%
Expected return on plan assets	6.56%	6.48%	6.27%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.30%	5.60%	2.99%
Expected return on plan assets	6.25%	6%	5.50%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.25%	5.60%	3.04%
Expected return on plan assets	6.75%	6.75%	6.75%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%	2.70%
Pension Plan | Minimum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%	3.50%
Pension Plan | Minimum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%	2.70%
Pension Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%
Pension Plan | Maximum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%
Pension Plan | Maximum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.34%	5.65%	3.04%
Expected return on plan assets	5.90%	5.51%	4.77%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.30%	5.65%	3.05%
Expected return on plan assets	5.88%	5.52%	4.80%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.35%	5.65%	3.05%
Expected return on plan assets	5.86%	5.47%	4.71%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%	2.70%
Other Postretirement Benefits Plan | Minimum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%	3.50%
Other Postretirement Benefits Plan | Minimum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%	2.70%
Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan | Maximum | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan | Maximum | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%	10%

EMPLOYEE BENEFIT PLANS - ASSUME

EMPLOYEE BENEFIT PLANS - ASSUMED HEALTH CARE COST TREND RATES (Details)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.34%	5.65%	3.04%
Expected return on plan assets	5.90%	5.51%	4.77%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Rate of compensation increase	2.70%	2.70%	2.70%
Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan | Pre-65 retirees
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.50%	6%	6%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
Other Postretirement Benefits Plan | Retirees aged 65 years and older
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	4.50%	4.50%	4.50%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.30%	5.65%	3.05%
Expected return on plan assets	5.88%	5.52%	4.80%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | SDG&E | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%
Rate of compensation increase	3.50%	3.50%	3.50%
Other Postretirement Benefits Plan | SDG&E | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan | SDG&E | Pre-65 retirees
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.50%	6%	6%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
Other Postretirement Benefits Plan | SDG&E | Retirees aged 65 years and older
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	4.50%	4.50%	4.50%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.35%	5.65%	3.05%
Expected return on plan assets	5.86%	5.47%	4.71%
Interest crediting rate	4.66%	3.99%	1.94%
Other Postretirement Benefits Plan | SoCalGas | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Rate of compensation increase	2.70%	2.70%	2.70%
Other Postretirement Benefits Plan | SoCalGas | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%
Other Postretirement Benefits Plan | SoCalGas | Pre-65 retirees
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.50%	6%	6%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
Other Postretirement Benefits Plan | SoCalGas | Retirees aged 65 years and older
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	4.50%	4.50%	4.50%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.31%	5.63%	3.04%
Expected return on plan assets	6.56%	6.48%	6.27%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Rate of compensation increase	2.70%	2.70%	2.70%
Pension Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.30%	5.60%	2.99%
Expected return on plan assets	6.25%	6%	5.50%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | SDG&E | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.50%	3.50%
Rate of compensation increase	3.50%	3.50%	3.50%
Pension Plan | SDG&E | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.25%	5.60%	3.04%
Expected return on plan assets	6.75%	6.75%	6.75%
Interest crediting rate	4.66%	3.99%	1.94%
Pension Plan | SoCalGas | Minimum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	2.70%	2.70%
Rate of compensation increase	2.70%	2.70%	2.70%
Pension Plan | SoCalGas | Maximum
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	10%	10%
Rate of compensation increase	10%	10%	10%

EMPLOYEE BENEFIT PLANS - TARGET

EMPLOYEE BENEFIT PLANS - TARGET ASSET ALLOCATIONS FOR SEMPRA’S PENSION MASTER TRUST (Details)	Dec. 31, 2024
Return Seeking Assets | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	34%
Return Seeking Assets | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	42%
Return Seeking Assets | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	49%
Return Seeking Assets | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	74%
Return Seeking Assets | Other Postretirement Benefits Plan | SDG&E and SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	38%
Return Seeking Assets | Other Postretirement Benefits Plan | SDG&E and SoCalGas | Voluntary Employee Beneficiary Association Trust
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	30%
Risk Mitigating Assets | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	66%
Risk Mitigating Assets | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	58%
Risk Mitigating Assets | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	51%
Risk Mitigating Assets | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	26%
Risk Mitigating Assets | Other Postretirement Benefits Plan | SDG&E and SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	62%
Risk Mitigating Assets | Other Postretirement Benefits Plan | SDG&E and SoCalGas | Voluntary Employee Beneficiary Association Trust
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	70%

EMPLOYEE BENEFIT PLANS - NARRAT

EMPLOYEE BENEFIT PLANS - NARRATIVE (Details) - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]
Market value of employer stock held by plan	$ 1.2	$ 1.1
Minimum | Return Seeking Assets
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4%
Minimum | Risk Mitigating Assets
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	2%
Maximum | Return Seeking Assets
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	12%
Maximum | Risk Mitigating Assets
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6%

EMPLOYEE BENEFIT PLANS - FAIR V

EMPLOYEE BENEFIT PLANS - FAIR VALUE MEASUREMENTS, INVESTMENT ASSETS OF PENSION PLANS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 2,935	$ 2,664	$ 2,390
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	787	726	670
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,937	1,744	1,535
Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	211	194
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,185	1,169	1,096
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	145	150	147
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,008	990	$ 923
Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	32	29
Fair Value, Inputs, Level 1, 2 and 3 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	378	503
Fair Value, Inputs, Level 1, 2 and 3 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	718	1,217
Fair Value, Inputs, Level 1, 2 and 3 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	111	136
Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	97	110
Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	638	749
Fair Value, Inputs, Level 1, 2 and 3 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	21
Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	297	426
Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	464	955
Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	91	118
Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	91	103
Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	171	286
Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	15
Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	81	77
Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	254	262
Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	20	18
Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	7
Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	467	463
Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	6
Cash and cash equivalents | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	17
Cash and cash equivalents | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	3
Cash and cash equivalents | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		7
Cash and cash equivalents | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Cash and cash equivalents | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	7
Cash and cash equivalents | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	17
Cash and cash equivalents | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	3
Cash and cash equivalents | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		7
Cash and cash equivalents | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Cash and cash equivalents | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	7
Cash and cash equivalents | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Cash and cash equivalents | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Cash and cash equivalents | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
Cash and cash equivalents | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Cash and cash equivalents | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, Domestic | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	103
Equity securities, Domestic | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	354
Equity securities, Domestic | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	23
Equity securities, Domestic | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	8
Equity securities, Domestic | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	57
Equity securities, Domestic | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		7
Equity securities, Domestic | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	103
Equity securities, Domestic | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	353
Equity securities, Domestic | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	22
Equity securities, Domestic | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	8
Equity securities, Domestic | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	57
Equity securities, Domestic | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		7
Equity securities, Domestic | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, Domestic | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	1
Equity securities, Domestic | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	1
Equity securities, Domestic | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, Domestic | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, Domestic | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
Equity securities, International | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	40
Equity securities, International | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	14	137
Equity securities, International | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	8
Equity securities, International | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		3
Equity securities, International | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	22
Equity securities, International | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	3
Equity securities, International | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	40
Equity securities, International | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	14	137
Equity securities, International | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	8
Equity securities, International | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		3
Equity securities, International | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	22
Equity securities, International | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	3
Equity securities, International | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, International | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, International | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, International | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
Equity securities, International | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Equity securities, International | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Registered investment companies – Domestic | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	48	41
Registered investment companies – Domestic | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	149	142
Registered investment companies – Domestic | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	8
Registered investment companies – Domestic | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	74	71
Registered investment companies – Domestic | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	190	181
Registered investment companies – Domestic | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	3
Registered investment companies – Domestic | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	48	41
Registered investment companies – Domestic | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	149	141
Registered investment companies – Domestic | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	8
Registered investment companies – Domestic | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	74	71
Registered investment companies – Domestic | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	87	78
Registered investment companies – Domestic | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	3
Registered investment companies – Domestic | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Registered investment companies – Domestic | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	1
Registered investment companies – Domestic | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Registered investment companies – Domestic | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Registered investment companies – Domestic | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	103	103
Registered investment companies – Domestic | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Registered investment companies – International | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	7
Registered investment companies – International | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	7
Registered investment companies – International | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic government and government agencies | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	232	245
Domestic government and government agencies | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	287	326
Domestic government and government agencies | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	80	80
Domestic government and government agencies | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	13
Domestic government and government agencies | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	88	142
Domestic government and government agencies | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	3
Domestic government and government agencies | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	227	240
Domestic government and government agencies | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	270	310
Domestic government and government agencies | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	77	78
Domestic government and government agencies | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	12
Domestic government and government agencies | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	74	128
Domestic government and government agencies | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	2
Domestic government and government agencies | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	5
Domestic government and government agencies | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	17	16
Domestic government and government agencies | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
Domestic government and government agencies | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	1
Domestic government and government agencies | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	14	14
Domestic government and government agencies | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
International government bonds | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
International government bonds | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	5
International government bonds | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
International government bonds | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	9
International government bonds | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International government bonds | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International government bonds | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
International government bonds | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International government bonds | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
International government bonds | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	5
International government bonds | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
International government bonds | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	9
Domestic corporate bonds | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	65	62
Domestic corporate bonds | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	201	212
Domestic corporate bonds | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	14	13
Domestic corporate bonds | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	5
Domestic corporate bonds | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	295	295
Domestic corporate bonds | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4
Domestic corporate bonds | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Domestic corporate bonds | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	65	62
Domestic corporate bonds | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	201	212
Domestic corporate bonds | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	14	13
Domestic corporate bonds | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	5
Domestic corporate bonds | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	295	295
Domestic corporate bonds | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4
International corporate bonds | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	8
International corporate bonds | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	27
International corporate bonds | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	2
International corporate bonds | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
International corporate bonds | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	45	42
International corporate bonds | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
International corporate bonds | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International corporate bonds | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International corporate bonds | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International corporate bonds | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International corporate bonds | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
International corporate bonds | Level 1 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
International corporate bonds | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	8
International corporate bonds | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	27
International corporate bonds | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	2
International corporate bonds | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
International corporate bonds | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	45	42
International corporate bonds | Level 2 | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
Derivative financial instruments | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	(15)
Derivative financial instruments | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(3)	11
Derivative financial instruments | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	(5)
Derivative financial instruments | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(1)	2
Derivative financial instruments | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	(6)
Derivative financial instruments | Level 1 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	(15)
Derivative financial instruments | Level 1 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(4)	11
Derivative financial instruments | Level 1 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	(5)
Derivative financial instruments | Level 1 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(1)	2
Derivative financial instruments | Level 1 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	(6)
Derivative financial instruments | Level 2 | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Derivative financial instruments | Level 2 | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0
Derivative financial instruments | Level 2 | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Derivative financial instruments | Level 2 | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Derivative financial instruments | Level 2 | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Accounts receivable/payable, net | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	1
Accounts receivable/payable, net | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	22	(12)
Accounts receivable/payable, net | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Accounts receivable/payable, net | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	(2)
Accounts receivable/payable, net | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	4
Investments measured at NAV – Common/collective trusts | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	406	214
Investments measured at NAV – Common/collective trusts | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,197	513
Investments measured at NAV – Common/collective trusts | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	99	56
Investments measured at NAV – Common/collective trusts | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	10
Investments measured at NAV – Common/collective trusts | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	361	233
Investments measured at NAV – Common/collective trusts | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	22	7
Other | Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		8
Other | Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		26
Other | Pension Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		2
Other | Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	32
Other | Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		4
Other | Other Postretirement Benefits Plan | Other Sempra
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
Total investment assets in the fair value hierarchy | Level 1 | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	852	1,499
Total investment assets in the fair value hierarchy | Level 1 | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	267	404
Total investment assets in the fair value hierarchy | Level 2 | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	355	357
Total investment assets in the fair value hierarchy | Level 2 | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 478	$ 476

EMPLOYEE BENEFIT PLANS - EXPECT

EMPLOYEE BENEFIT PLANS - EXPECTED CONTRIBUTIONS (Details) $ in Millions	Dec. 31, 2024 USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	$ 280
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	54
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	188
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	3
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	1
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	$ 1

EMPLOYEE BENEFIT PLANS - EXPE_2

EMPLOYEE BENEFIT PLANS - EXPECTED BENEFIT PAYMENTS (Details) $ in Millions	Dec. 31, 2024 USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
2025	$ 276
2026	246
2027	258
2028	236
2029	230
2030-2034	1,161
Pension Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
2025	68
2026	63
2027	62
2028	67
2029	61
2030-2034	305
Pension Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
2025	162
2026	151
2027	146
2028	144
2029	143
2030-2034	721
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
2025	48
2026	50
2027	46
2028	46
2029	46
2030-2034	229
Other Postretirement Benefits Plan | SDG&E
Defined Benefit Plan Disclosure [Line Items]
2025	11
2026	10
2027	10
2028	10
2029	10
2030-2034	47
Other Postretirement Benefits Plan | SoCalGas
Defined Benefit Plan Disclosure [Line Items]
2025	35
2026	34
2027	34
2028	34
2029	34
2030-2034	$ 171

EMPLOYEE BENEFIT PLANS - EMPLOY

EMPLOYEE BENEFIT PLANS - EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 65	$ 59	$ 64
SDG&E
Savings Plan [Line Items]
Employer contributions to defined benefit plan	22	20	19
SoCalGas
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 33	$ 32	$ 30

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - COMMODITY VOLUMES (Details)	12 Months Ended
	Dec. 31, 2024 MWh MMBTU	Dec. 31, 2023 MMBTU MWh
Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	637	361
Natural gas | SDG&E
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	16	17
Natural gas | SoCalGas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	347	268
Electricity
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MWh	0	1
Congestion revenue rights
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MWh	27	36
Congestion revenue rights | SDG&E
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MWh	27	36

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES NARRATIVE (Details) - Interest rate instruments - Port Arthur LNG - USD ($) $ in Millions			1 Months Ended
	Dec. 31, 2024	Sep. 30, 2024	Oct. 31, 2024
Derivatives, Fair Value [Line Items]
Deferred gains on derivative	$ 37	$ 40
Termination of interest rate and settlement of cross-currency swaps			$ 46
Notional amounts			$ 1,000

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Oct. 31, 2024	Dec. 31, 2023
Interest rate instruments | Port Arthur LNG
Derivative [Line Items]
Notional amounts		$ 1,000
Interest rate instruments | Cash Flow Hedges
Derivative [Line Items]
Notional amount of derivative liability	$ 271		$ 4,451
Interest rate swap | Derivatives not designated as hedging instruments:
Derivative [Line Items]
Notional amount of derivative liability	3,189		0
Interest rate swap | Cash Flow Hedges
Derivative [Line Items]
Notional amounts	271		488
Foreign currency derivatives
Derivative [Line Items]
Notional amount of derivative liability	$ 162		$ 176

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - BALANCE SHEET (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Current assets: Fixed-price contracts and other derivatives
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	$ 26	$ 26
Derivative asset, Additional cash collateral for commodity contracts not subject to rate recovery	40	74
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	25	22
Derivative assets, Total	$ 91	$ 122
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other current assets	Other current assets
Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	$ 277	$ 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	$ 277	$ 77
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other long-term assets	Other long-term assets
Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	$ (46)	$ (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 Liability, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Derivative liabilities, Total	$ (46)	$ (221)
Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(24)	(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 Liability, Statement of Financial Position [Extensible Enumeration]	Deferred credits and other	Deferred credits and other
Derivative liabilities, Total	$ (24)	$ (5)
Derivatives designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Interest rate instruments
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	7	17
Derivatives designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	4	0
Derivatives designated as hedging instruments: | Other long-term assets | Interest rate instruments
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	28	70
Derivatives designated as hedging instruments: | Other long-term assets | Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	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	0	(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	0	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: | Current assets: Fixed-price contracts and other derivatives | Interest rate instruments
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	12
Derivatives not designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	16	173
Derivative asset, subject to master netting arrangement, liability offset	(15)	(169)
Derivatives not designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	7	10
Derivative asset, subject to master netting arrangement, liability offset	(5)	(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]
Commodity contracts subject to rate recovery	246
Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	23	52
Derivative asset, subject to master netting arrangement, liability offset	(23)	(51)
Derivatives not designated as hedging instruments: | Other long-term assets | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	4	8
Derivative asset, subject to master netting arrangement, liability offset	(2)	(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	(21)	(170)
Derivative liability, subject to master netting arrangement, asset offset	15	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	(55)	(228)
Derivative liability, subject to master netting arrangement, asset offset	5	5
Associated offsetting cash collateral	10	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	(43)	(56)
Derivative liability, subject to master netting arrangement, asset offset	23	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	(10)	(9)
Derivative liability, subject to master netting arrangement, asset offset	2	2
Associated offsetting cash collateral	4	7
SDG&E | Current assets: Fixed-price contracts and other derivatives
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	2	4
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	21	21
Derivative assets, Total	$ 23	$ 25
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other current assets	Other current assets
SDG&E | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	$ 2	$ 6
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	$ 2	$ 6
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other long-term assets	Other long-term assets
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 Liability, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
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 Liability, Statement of Financial Position [Extensible Enumeration]	Deferred credits and other	Deferred credits and other
Derivative liabilities, Total	$ 0	$ 0
SDG&E | Derivatives not designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	4	9
Derivative asset, subject to master netting arrangement, liability offset	(2)	(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]
Commodity contracts subject to rate recovery	4	8
Derivative asset, subject to master netting arrangement, liability offset	(2)	(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	(13)	(18)
Derivative liability, subject to master netting arrangement, asset offset	2	5
Associated offsetting cash collateral	10	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	(6)	(9)
Derivative liability, subject to master netting arrangement, asset offset	2	2
Associated offsetting cash collateral	4	7
SoCalGas | Current assets: Fixed-price contracts and other derivatives
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	4	1
Derivative assets, Total	$ 4	$ 2
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other current assets	Other current assets
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
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other long-term assets	Other long-term assets
SoCalGas | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	$ (39)	$ (210)
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	$ 0	$ 0
Derivative Liability, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Derivative liabilities, Total	$ (39)	$ (210)
SoCalGas | Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(4)	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	$ 0	$ 0
Derivative Liability, Statement of Financial Position [Extensible Enumeration]	Deferred credits and other	Deferred credits and other
Derivative liabilities, Total	$ (4)	$ 0
SoCalGas | Derivatives not designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	(3)
SoCalGas | Derivatives not designated as hedging instruments: | Current assets: Fixed-price contracts and other derivatives | Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Commodity contracts subject to rate recovery	3	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]
Commodity contracts subject to rate recovery	0	0
SoCalGas | Derivatives not designated as hedging instruments: | Other current liabilities
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	3
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	(42)	(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	$ (4)	$ 0

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - INCOME STATEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 37	$ 1	$ 216
Cost of natural gas
Derivative Instruments, Gain (Loss) [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 electric fuel and purchased power
Derivative Instruments, Gain (Loss) [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
Commodity contracts not subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Unregulated Operating Revenue	Unregulated Operating Revenue	Unregulated Operating Revenue
Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense, Nonoperating	Interest Expense, Nonoperating	Interest Expense, Nonoperating
Derivatives designated as hedging instruments: | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	$ 85	$ 67	$ 257
Pretax gain (loss) reclassified from AOCI into earnings	47	49	(16)
Derivatives designated as hedging instruments: | Cash Flow Hedges | Interest rate instruments | Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	36	45	40
Pretax gain (loss) reclassified from AOCI into earnings	11	(1)	(1)
Derivatives designated as hedging instruments: | Cash Flow Hedges | Interest rate instruments | Equity Earnings
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	21	20	205
Pretax gain (loss) reclassified from AOCI into earnings	23	48	(29)
Derivatives designated as hedging instruments: | Cash Flow Hedges | Foreign exchange instruments | Equity Earnings
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	12	(3)	(5)
Pretax gain (loss) reclassified from AOCI into earnings	6	(2)	0
Derivatives designated as hedging instruments: | Cash Flow Hedges | Foreign exchange instruments | Revenues: Energy- related businesses
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	14	(2)	(8)
Pretax gain (loss) reclassified from AOCI into earnings	5	(1)	1
Derivatives designated as hedging instruments: | Cash Flow Hedges | Foreign exchange instruments | Other income, net
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	2	(2)	(1)
Derivatives designated as hedging instruments: | Cash Flow Hedges | Interest rate and foreign exchange instruments | Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	7	25
Pretax gain (loss) reclassified from AOCI into earnings	0	1	2
Derivatives designated as hedging instruments: | Cash Flow Hedges | Interest rate and foreign exchange instruments | Other income, net
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	0	6	12
Derivatives designated as hedging instruments: | Fair Value Hedging | Foreign currency derivatives | Equity Earnings
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	2	0	0
Pretax gain (loss) reclassified from AOCI into earnings	0	0	0
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	369	599	(937)
Derivatives not designated as hedging instruments: | Commodity contracts not subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	223	919	(1,116)
Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery | Cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(56)	(288)	(56)
Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery | Cost of electric fuel and purchased power
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(41)	15	202
Derivatives not designated as hedging instruments: | Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	243	(47)	33
SDG&E | Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(41)	15	202
SoCalGas | Derivatives designated as hedging instruments: | Cash Flow Hedges | Interest rate instruments | Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0
Pretax gain (loss) reclassified from AOCI into earnings	(1)	(1)	(1)
SoCalGas | Derivatives not designated as hedging instruments: | Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	$ (56)	$ (288)	$ (56)

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES ADDITIONAL INFORMATION (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ 29
Cash flow hedge gain (loss) to be reclassified within 12 months, attributable to noncontrolling interest	$ 10
Maximum length of time hedged in cash flow hedge	1 year
SoCalGas
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (1)

DERIVATIVE FINANCIAL INSTRUME_9

DERIVATIVE FINANCIAL INSTRUMENTS - CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	$ 122	$ 215
Aggregate fair value of additional collateral	120
SoCalGas
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	42	$ 210
Aggregate fair value of additional collateral	$ 42

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Fair Value, Recurring - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	$ 890	$ 879
Short-term investments held in Rabbi Trust	64	67
Support Agreement, net of related guarantee fees	25	23
Netting adjustment	20	96
Total	1,347	1,168
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(59)	(19)
Total	70	226
Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	10	21
Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	298	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	67	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	228	220
Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	582	546
Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0	0
Derivative assets, Total	293	87
Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0
Derivative assets, Total	5
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment		0
Derivative liabilities		9
Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	2	74
Derivative assets, Total	41	79
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(38)	0
Derivative liabilities	26	6
Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	18	22
Derivative assets, Total	29	33
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(21)	(19)
Derivative liabilities	44	211
Level 1
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	344	361
Short-term investments held in Rabbi Trust	64	67
Support Agreement, net of related guarantee fees	0	0
Total	414	428
Liabilities, Fair Value Disclosure [Abstract]
Total	21	20
Level 1 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	8	19
Level 1 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	295	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	41	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	41	34
Level 1 | Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
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
Level 1 | 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	1	0
Level 1 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	20	20
Level 2
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	546	518
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	884	611
Liabilities, Fair Value Disclosure [Abstract]
Total	108	225
Level 2 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	2	2
Level 2 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	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	26	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	228	220
Level 2 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	541	512
Level 2 | Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	293	87
Level 2 | Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	5
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting		9
Level 2 | Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	39	5
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	63	6
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	45	210
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	25	23
Total	29	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
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
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	4	10
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SDG&E
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	890	879
Netting adjustment	17	21
Total	915	910
SDG&E | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	10	21
SDG&E | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	298	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	67	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	228	220
SDG&E | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	582	546
SDG&E | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	17	21
Derivative assets, Total	25	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	344	361
Total	348	361
SDG&E | Level 1 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	8	19
SDG&E | Level 1 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	295	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	41	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	41	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	546	518
Total	546	518
SDG&E | Level 2 | Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	2	2
SDG&E | Level 2 | Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	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	26	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	228	220
SDG&E | Level 2 | Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	541	512
SDG&E | Level 2 | 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	1	0
SDG&E | Level 3
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Total	4	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	4	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	4	2
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(3)	0
Derivative liabilities	43	210
SoCalGas | Level 1 | Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	2	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	2	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	44	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	12 Months Ended
	Dec. 31, 2025 USD ($) $ / MWh	Dec. 31, 2024 USD ($) $ / MWh	Dec. 31, 2023 USD ($) $ / MWh	Dec. 31, 2022 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FairValueRecurringBasisUnobservableInputReconciliationNetDerivativeAssetLiabilityGainLossStatementOfIncomeExtensibleListNotDisclosedFlag		Realized and unrealized gains (losses), net
Other Sempra
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 25	$ 23	$ 17	$ 7
Realized and unrealized gains		11	15	19
Settlements		(9)	(9)	(9)
Ending balance		25	23	17
Change in unrealized gains relating to instruments still held at December 31		8	13	18
Level 3 | SDG&E
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at beginning of period	$ 4	10	35	54
Realized and unrealized gains (losses), net		(10)	(17)	(56)
Allocated transmission instruments		3	(1)	(4)
Settlements		1	(7)	41
Balance at end of period		4	10	35
Change in unrealized gains (losses) relating to derivative instruments still held at the end of the period		$ (4)	$ (13)	$ (10)
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)
Market electricity forward price inputs (in dollars per MWH) | $ / MWh				33.45
Level 3 | SDG&E | Minimum | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	(7.38)
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
Market electricity forward price inputs (in dollars per MWH) | $ / MWh				274.70
Level 3 | SDG&E | Maximum | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	15.54
Level 3 | SDG&E | Median
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh		(0.44)	(0.56)
Level 3 | SDG&E | Median | Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) | $ / MWh	0.01
Level 3 | SDG&E | Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (in dollars per MWH) | $ / MWh				85.64
Level 3 | Other Sempra | Other Current Assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 7	$ 7
Ending balance		7	$ 7
Level 3 | Other Sempra | Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 18	16
Ending balance		$ 18	$ 16

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, allowance for credit losses	$ 5	$ 6
Notes receivable, unamortized issuance costs	3	4
Unamortized discount (net of premium) and debt issuance costs	382	322
Finance lease obligations	1,315	1,340
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	351	334
Long-term amounts due to unconsolidated affiliates	352	312
Total long-term debt	32,899	27,716
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	334	318
Long-term amounts due to unconsolidated affiliates	324	283
Total long-term debt	30,193	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	324	283
Total long-term debt	30,193	25,617
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	334	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 (net of premium) and debt issuance costs	95	89
Finance lease obligations	1,205	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	7,760	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	7,760	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 (net of premium) and debt issuance costs	65	55
Finance lease obligations	110	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	6,880	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	6,880	6,442
SoCalGas | Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

PREFERRED STOCK - Narrative (De

PREFERRED STOCK - Narrative (Details)	12 Months Ended		64 Months Ended
	Dec. 31, 2024 vote $ / shares shares	Dec. 31, 2023 shares	Oct. 14, 2025	May 02, 2024 shares	May 01, 2024 shares
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
Preferred Class C
Preferred Stock [Line Items]
Preferred stock, shares outstanding (in shares)	900,000	900,000
Preferred stock redemption price (in dollars per share) | $ / shares	$ 1,000
Liquidation preference per share (as a percent)	102%
Preferred stock dividend rate (as a percent)	4.875%	4.875%
Liquidation preference (in dollars per share) | $ / shares	$ 1,020
Preferred Class C | Period one | Forecast | Subsequent Event
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)			4.875%
Preferred Class C | Period two
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	4.55%
Liquidation preference (in dollars per share) | $ / shares	$ 1,000
SDG&E
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares outstanding (in shares)	0	0
SoCalGas
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	862,043	862,043
Number of votes per share | vote	1
SoCalGas | Twenty Five Dollar Par, Six Percent Series A
Preferred Stock [Line Items]
Preferred stock, shares outstanding (in shares)	783,032
Preferred stock dividend rate (as a percent)	6%
Liquidation preference (in dollars per share) | $ / shares	$ 25
SoCalGas | SoCalGas Series Preferred Stock
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	5,000,000
SoCalGas | Twenty Five Dollar Par, Six Percent Series
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	1,000,000
Preferred stock, shares outstanding (in shares)	79,011
Preferred stock dividend rate (as a percent)	6%
Liquidation preference (in dollars per share) | $ / shares	$ 25

PREFERRED STOCK - Schedule of P

PREFERRED STOCK - Schedule of Preferred Stock Outstanding (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
SoCalGas
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	862,043	862,043
Twenty Five Dollar Par, Six Percent Series | SoCalGas
Preferred Stock [Line Items]
Par value (in dollars per share)	$ 25
Preferred stock, shares authorized (in shares)	1,000,000
Preferred stock dividend rate (as a percent)	6%
Preferred stock, shares outstanding (in shares)	79,011
Preferred stock outstanding	$ 3	$ 3
Twenty Five Dollar Par, Six Percent Series A | SoCalGas
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	6%
Preferred stock, shares outstanding (in shares)	783,032
Preferred stock outstanding	$ 19	19
SoCalGas Series Preference Stock | SoCalGas
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	5,000,000
SoCalGas Preferred Stock Owned by Pacific Enterprises
Preferred Stock [Line Items]
Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises	$ (2)	(2)
SoCalGas Preferred Stock Owned by Pacific Enterprises | SoCalGas
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	6%
Preferred stock, shares outstanding (in shares)	50,970
Preferred Stock Of Subsidiaries
Preferred Stock [Line Items]
Preferred stock outstanding	$ 20	20
SoCalGas Series Preferred Stock | SoCalGas
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	5,000,000
Preferred stock outstanding	$ 22	$ 22

SEMPRA - EQUITY AND EARNINGS _3

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - COMMON STOCK ACTIVITY (Details) - shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares outstanding, January 1	631,431,732	628,669,356	633,839,564
Shares issued under forward sale agreements	17,142,858	0	0
Shares issued to underwriters to cover overallotments	0	2,099,152	0
RSUs vesting	1,320,561	941,910	914,444
Stock options exercised	143,944	0	81,260
Common stock investment plan	1,151,877	1,730	0
Issuance of RSUs held in our Deferred Compensation Plan	128,207	132,178	130,026
Shares repurchased	(689,303)	(412,594)	(6,295,938)
Common shares outstanding, December 31	650,629,876	631,431,732	628,669,356

SEMPRA - EQUITY AND EARNINGS _4

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NARRATIVE (Details) - USD ($)					1 Months Ended			12 Months Ended
	Feb. 25, 2025	Dec. 31, 2024	Apr. 06, 2022	Jan. 11, 2022	Dec. 31, 2024	Nov. 30, 2023	Jun. 30, 2022	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2024	Dec. 21, 2021	Jul. 06, 2020
Common stock, shares authorized (in shares)		1,125,000,000			1,125,000,000			1,125,000,000	1,125,000,000
Sale of stock, number of shares issued in transaction (in shares)						19,242,010
Issuances of common stock, net						$ 144,000,000		$ 1,219,000,000	$ 145,000,000	$ 4,000,000
Payments of stock issuance costs		$ 2,000,000				$ 3,000,000
Sales									$ 1,234,000,000	$ 1,419,000,000
SI Partners | Sempra Infrastructure
Sales							$ 709,000,000
Sale of noncontrolling interest, change in equity							710,000,000
Sale of noncontrolling interest, transaction costs							12,000,000
Sale of noncontrolling interest, deferred income tax liability							300,000,000
Sale of noncontrolling interest, transaction costs reimbursed							$ 10,000,000
Abu Dhabi Investment Authority | SI Partners
Sale of noncontrolling interest, purchase price												$ 1,700,000,000
Ownership percentage held by noncontrolling owners												10%
Subsequent Event
Maximum amount of shares that may yet be purchased	$ 1,250,000,000
Shares may yet be purchased (in shares)	19,632,529
Public Stock Offering
Forward price per share (in usd per share)		$ 69.2195			$ 69.2195			$ 69.2195
Sale of stock, number of shares issued in transaction (in shares)					17,142,858	17,142,858
Par value (in usd per share)						$ 0
Sale of stock, price per share (in usd per share)						70
Sale of stock, price per share, after underwriting discounts (in usd per share)						$ 68.845
Issuances of common stock, net					$ 1,200,000,000
Payments of stock issuance costs					20,000,000
Over-Allotment Option
Sale of stock, number of shares issued in transaction (in shares)						2,099,152
At The Market Program Offering
Aggregate sales price											$ 3,000,000,000
Underwriting commission, percent											1%
Amount of stock available to be issued		$ 2,700,000,000			$ 2,700,000,000			$ 2,700,000,000
Number of shares available for issuance		2,909,274			2,909,274			2,909,274			2,909,274
Forward price per share (in usd per share)		$ 92.1546			$ 92.1546			$ 92.1546
Issuances of common stock, net		$ 268,000,000
Common Stock
Stock repurchase program, authorized amount													$ 2,000,000,000
Number of shares authorized to be repurchased (in shares)													25,000,000
Common shares repurchased (in shares)			2,943,914	2,945,512
Common shares repurchased, average price (in dollars per share)			$ 84.92	$ 67.90
ASR program, amount prepaid			$ 250,000,000	$ 200,000,000
Shares withheld for tax purposes (in shares)								689,303	412,594	406,512
Shares withheld for tax purposes								$ 43,000,000	$ 32,000,000	$ 28,000,000

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	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Earnings Per Share [Abstract]
Net of tax amount, attributable to parent	$ 2,862	$ 3,075	$ 2,139
(Decrease) increase in shareholders’ equity for sales of NCI		(49)	710
Net transfers (to) from NCI		(49)	710
Change from net income attributable to Sempra and transfers (to) from NCI		$ 3,026	$ 2,849

SEMPRA - EQUITY AND EARNINGS _6

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NONCONTROLLING INTERESTS NARATIVE (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Sep. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 21, 2021	Oct. 31, 2021
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest					$ 1,234	$ 1,419
Contributions				$ 1,235	1,625	31
Net income, income tax expense (benefit), attributable to parent				$ 219	490	$ 556
SI Partners | Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest, purchase price							$ 1,700
Ownership percentage held by noncontrolling owners							10%
SI Partners | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest			$ 709
Sale of noncontrolling interest, change in equity			710
Sale of noncontrolling interest, transaction costs			12
Sale of noncontrolling interest, deferred income tax liability			300
Sale of noncontrolling interest, transaction costs reimbursed			$ 10
Ownership interest (as a percent)				70%
Port Arthur LNG | SI Partners | KKR Denali
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	42%
Port Arthur LNG | Indirect Subsidiary Of SI Partners
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		30%
Noncontrolling interest, funding commitment, percentage		110%
Noncontrolling interest, guaranteed funding commitment, percentage		70%
SI Partners Subsidiary | Indirect Subsidiary Of SI Partners | KKR Denali
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	60%
Port Arthur LNG
Noncontrolling Interest [Line Items]
Contributions		$ 234
Port Arthur LNG | KKR Denali
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest	$ 61
Contributions	1,000
Noncontrolling interest, increase from sale of parent equity interest, transaction costs	11
Noncontrolling interest, increase from sale of parent equity interest, tax expense (benefit)	(23)
Port Arthur LNG | SI Partners | KKR Denali
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest, cash consideration, minimum interest transferred	$ 976
Port Arthur LNG | Indirect Subsidiary Of SI Partners
Noncontrolling Interest [Line Items]
Noncontrolling interest, funding commitment		9,000
Contributions		12
Noncontrolling interest, increase from sale of parent equity interest, transaction costs		3
Noncontrolling interest, increase from sale of parent equity interest, tax expense (benefit)		5
Proceeds from divestiture of interest in joint venture		$ 254
Funding commitment paid				$ 2,700
SI Partners
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest					200
Sale of noncontrolling interest, change in equity					145
SI Partners | KKR
Noncontrolling Interest [Line Items]
Noncontrolling interest, funding commitment								$ 200
Payments to noncontrolling interests					$ 200

SEMPRA - EQUITY AND EARNINGS _7

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - EARNINGS (LOSSES) PER COMMON SHARE COMPUTATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Earnings Per Share [Abstract]
Earnings attributable to common shares	$ 2,817	$ 3,030	$ 2,094
Earnings attributable to common shares, diluted	$ 2,817	$ 3,030	$ 2,094
Weighted-average common shares outstanding for basic EPS (in shares)	633,795	630,296	630,318
Dilutive effect of stock options and RSUs (in shares)	2,112	2,341	2,439
Dilutive effect of common shares sold forward (in shares)	2,036	96	0
Weighted-average number of shares outstanding, diluted (in shares)	637,943	632,733	632,757
Basic earnings per common share (usd per share)	$ 4.44	$ 4.81	$ 3.32
Diluted earnings per common share (usd per share)	$ 4.42	$ 4.79	$ 3.31
Fully vested RSUs included in the computation of EPS	617	717	805

SEMPRA - EQUITY AND EARNINGS _8

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - ANTIDILUTIVE SECURITIES EXCLUDED FROM COMPUTATION OF EPS (Details) - shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Stock options, RSAs and RSUs
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS (in shares)	747,724	502,942	173,064

SHARE-BASED COMPENSATION - SHAR

SHARE-BASED COMPENSATION - SHARE-BASED COMPENSATION EXPENSE/ OPTIONS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Number of shares authorized for issuance (in shares)	15,400,000
Number of shares available for future grants (in shares)	7,628,467
Share-based compensation expense, before income taxes	$ 77	$ 71	$ 61
Income tax benefit	(9)	(9)	(17)
Share-based compensation expense, net	68	62	44
Capitalized share-based compensation cost	13	12	11
Excess income tax (benefit) deficiency	$ (9)	$ (6)	$ (3)
Non-qualified stock options granted (in shares)	414,812	326,574	439,796
Exercised Options, Net Settlement	(23,713)
Stock option exercise period (in years)	3 years
Weighted-average fair value for options granted (in dollars per share)	$ 16.43	$ 17.50	$ 10.99
Stock price volatility (as a percent)	26.49%	27.35%	26.08%
Expected term (in years)	5 years 4 months 9 days	5 years 4 months 9 days	5 years 4 months 9 days
Risk-free rate of return (as a percent)	3.90%	3.89%	1.40%
Annual dividend yield (as a percent)	3.14%	2.98%	3.33%
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding [Roll Forward]
Beginning balance (in shares)	1,759,798
Options granted in period (in shares)	414,812	326,574	439,796
Exercised (in shares)	$ (9)	$ 0	$ 0
Withheld related to net settlement (in shares)	(120,231)
Ending balance (in shares)	2,030,666	1,759,798
Vested at period end (in shares)	2,030,666
Exercisable at period end (in shares)	1,251,544
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Abstract]
Beginning balance (in dollars per share)	$ 65.99
Granted (in dollars per share)	75.82
Exercised (in dollars per share)	62.87
Withheld related to net settlement (in dollars per share)	62.87
Ending balance (in dollars per share)	68.22	$ 65.99
Vested at period end, Weighted- average exercise price (in dollars per share)	68.22
Exercisable at period end, Weighted- average exercise price (in dollars per share)	$ 64.45
Outstanding at period end, Weighted- average remaining contractual term	6 years 9 months 10 days
Vested at period end, Weighted- average remaining contractual term	6 years 9 months 10 days
Exercisable at period end, Weighted- average remaining contractual term	5 years 9 months 21 days
Outstanding at period end, Aggregate intrinsic value	$ 40
Vested at period end, Aggregate intrinsic value	40
Exercisable at period end, Aggregate intrinsic value	29
Aggregate intrinsic value of options exercised	$ 4.4	$ 0	$ 1.7
Weighted average period over which unrecognized compensation cost will be recognized (in years)	7 months 6 days
Weighted-average per share fair value for nonqualified stock options granted (in dollars per share)		$ 76.86	$ 66
Cash received from exercise of options			$ 4
SDG&E
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	$ 12	$ 13	11
Income tax benefit	(2)	(2)	(3)
Share-based compensation expense, net	10	11	8
Capitalized share-based compensation cost	7	7	6
Excess income tax (benefit) deficiency	(1)	(1)	0
SoCalGas
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	20	18	17
Income tax benefit	(4)	(3)	(5)
Share-based compensation expense, net	16	15	12
Capitalized share-based compensation cost	6	5	5
Excess income tax (benefit) deficiency	$ (2)	$ (1)	$ 0
Share-based Payment Arrangement, Option
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Expiration period	10 years
Performance Shares
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Award vesting rights maximum additional award	100%
Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Minimum | Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years

SHARE-BASED COMPENSATION - RSAs

SHARE-BASED COMPENSATION - RSAs and RSUs (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free rate of return (as a percent)	3.90%	3.89%	1.40%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Maximum Performance Based RSU Target Performance Conditions Exceeded For Awards Granted during or after 2014	100%
Weighted average period over which unrecognized compensation cost will be recognized (in years)	7 months 6 days
Share-Based Compensation, Restricted Stock Awards And Units
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Stock price volatility (as a percent)	21.27%	35.31%	32.82%
Risk-free rate of return (as a percent)	4.06%	4.13%	1.05%
Share-Based Compensation, Performance Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	1,829,984
Granted (in shares)	721,049
Vested (in shares)	(571,322)
Forfeited (in shares)	(73,987)
Nonvested, end of period (in shares)	1,905,724	1,829,984
Expected to vest (in shares)	1,865,938
Nonvested, Weighted average grant date fair value, beginning of period (in dollars per share)	$ 74.46
Weighted average grant date fair value, granted (in dollars per share)	75.70	$ 82.64	$ 73.47
Weighted average grant date fair value, vested (in dollars per share)	66.52
Weighted average grant date fair value, forfeited (in dollars per share)	76.78
Nonvested, Weighted average grant date fair value, end of period (in dollars per share)	77.22	$ 74.46
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 77.19
Share-Based Compensation, Service Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	524,969
Granted (in shares)	321,576
Vested (in shares)	(281,494)
Forfeited (in shares)	(21,963)
Nonvested, end of period (in shares)	543,088	524,969
Expected to vest (in shares)	525,029
Nonvested, Weighted average grant date fair value, beginning of period (in dollars per share)	$ 70.63
Weighted average grant date fair value, granted (in dollars per share)	75.86	$ 76.76	$ 66.32
Weighted average grant date fair value, vested (in dollars per share)	68.68
Weighted average grant date fair value, forfeited (in dollars per share)	88.74
Nonvested, Weighted average grant date fair value, end of period (in dollars per share)	74.55	$ 70.63
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 74.49
Share-Based Compensation, Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity instruments other than options, vested in the period, fair value	$ 57	$ 52	$ 54
Nonvested awards, compensation cost not yet recognized	$ 43
Weighted average period over which unrecognized compensation cost will be recognized (in years)	1 year 9 months 18 days

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - SDG&E $ in Millions	Dec. 31, 2024 USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Percentage of environmental exit costs incurred	20%
San Onofre Nuclear Generating Station (SONGS)
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage	20%
SONGS Units 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount	$ 66

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	$ 669	$ 661
Gross unrealized gains	227	233
Gross unrealized losses	(21)	(22)
Estimated fair value	875	872
Proceeds from sales	874	592	$ 639
Gross realized gains	57	27	18
Gross realized losses	10	14	$ 20
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	10	21
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Estimated fair value	10	21
Equity securities
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	78	89
Gross unrealized gains	223	225
Gross unrealized losses	(3)	(2)
Estimated fair value	298	312
Domestic government and government agencies
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	67	50
Gross unrealized gains	1	2
Gross unrealized losses	(1)	(1)
Estimated fair value	67	51
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	295	280
Gross unrealized gains	1	3
Gross unrealized losses	(9)	(8)
Estimated fair value	287	275
Other securities
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	234	228
Gross unrealized gains	2	3
Gross unrealized losses	(8)	(11)
Estimated fair value	228	220
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	596	558
Gross unrealized gains	4	8
Gross unrealized losses	(18)	(20)
Estimated fair value	582	546
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Securities Held In Nuclear Decommissioning Trusts, Amortized Costs	(15)	(7)
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Estimated fair value	$ (15)	$ (7)

SAN ONOFRE NUCLEAR GENERATING_5

SAN ONOFRE NUCLEAR GENERATING STATION - ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL (Details) - SDG&E $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Decommissioning liability	$ 471
2025	89
2026	57
2027	37
2028	25
2029	11
Thereafter	$ 870

SAN ONOFRE NUCLEAR GENERATING_6

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - SDG&E $ in Millions	Dec. 31, 2024 USD ($)
Public Utilities, General Disclosures [Line Items]
Maximum required nuclear liability insurance available	$ 500
Maximum secondary financial protection available	60
Maximum nuclear liability loss coverage per incident	560
Federal nuclear property damage insurance	130
Federal nuclear property damage insurance, minimum required	50
Maximum nuclear property insurance terrorism coverage	$ 3,240

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions	Dec. 31, 2024 USD ($)
Loss Contingencies [Line Items]
Loss contingency accrual	$ 41
SoCalGas
Loss Contingencies [Line Items]
Loss contingency accrual	$ 26

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - SDG&E AND SoCalGas LITIGATION (Details) $ in Millions		1 Months Ended	4 Months Ended	12 Months Ended
	Feb. 19, 2025 plaintiff	Sep. 30, 2021 USD ($) plaintiff lawsuit	Feb. 11, 2016 well	Dec. 31, 2024 USD ($) Bcf	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Aliso Canyon litigation and regulatory matters				$ 0	$ 0	$ 259
SoCalGas
Loss Contingencies [Line Items]
Injection and withdrawal wells with gas leak | well			1
Aliso Canyon litigation and regulatory matters				$ 0	$ 0	259
Natural gas inventory level, maximum | Bcf				68.6
SDG&E
Loss Contingencies [Line Items]
Number of pending claims | lawsuit							2
Aliso Canyon Natural Gas Storage Facility Gas Leak | SoCalGas
Loss Contingencies [Line Items]
Number of pending claims | lawsuit		390
Number of plaintiffs | plaintiff		36,000
Aliso Canyon litigation and regulatory matters						259
Aliso Canyon litigation and regulatory matters, net of tax						$ 199
Aliso Canyon Natural Gas Storage Facility Gas Leak | SoCalGas | Individual Plaintiff Litigation
Loss Contingencies [Line Items]
Estimate of possible loss		$ 1,800
Percentage of plaintiffs agreeing to participate						99%
Damages paid						$ 1,790
Aliso Canyon Natural Gas Storage Facility Gas Leak | SoCalGas | The Developer Plaintiffs | Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff	520

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - SEMPRA INFRASTRUCTURE (Details) - Sempra Infrastructure	12 Months Ended	48 Months Ended
	Dec. 31, 2024 segment	Dec. 31, 2021 claimant	Jul. 31, 2024 lawsuit
Loss Contingencies [Line Items]
Number of pending claims | lawsuit			3
Number of claimants | claimant		3
Number of segments of pipeline | segment	2

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LEASES BALANCE SHEET INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Lessee, Lease, Description [Line Items]
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant and equipment, net	Property, plant and equipment, net
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other current liabilities	Other current liabilities
Right-of-use assets – operating leases	$ 1,177	$ 723
Finance leases, property plant and equipment	1,626	1,585
Finance leases, accumulated depreciation	(311)	(246)
Finance leases, property plant and equipment, net	1,315	1,339
Total ROU assets	2,492	2,062
Operating lease, other current liabilities	$ 91	$ 70
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Deferred credits and other	Deferred credits and other
Operating lease, deferred credits and other	$ 1,019	$ 599
Total lease liabilities	$ 1,110	$ 669
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Current portion of long-term debt and finance leases	Current portion of long-term debt and finance leases
Finance lease, current portion of long-term debt and finance leases	$ 65	$ 64
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Long-term debt	Long-term debt
Long-term debt and finance leases	$ 1,250	$ 1,276
Total finance leases	1,315	1,340
Total lease liabilities	$ 2,425	$ 2,009
Operating lease, weighted-average remaining lease term	13 years	13 years
Finance lease, weighted-average remaining lease term	14 years	15 years
Operating lease, weighted-average discount rate (as a percent)	6.10%	6.64%
Finance lease, weighted-average discount rate (as a percent)	13.71%	13.80%
Other Operating Leases
Lessee, Lease, Description [Line Items]
Operating lease, weighted-average discount rate (as a percent)	7.41%	7.57%
Purchased-Power Agreements
Lessee, Lease, Description [Line Items]
Operating lease, other current liabilities	$ 43	$ 18
Operating lease, deferred credits and other	$ 627	$ 208
Operating lease, weighted-average discount rate (as a percent)	5.04%	4.19%
SDG&E
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 795	$ 368
Finance leases, property plant and equipment	1,426	1,412
Finance leases, accumulated depreciation	(221)	(179)
Finance leases, property plant and equipment, net	1,205	1,233
Total ROU assets	2,000	1,601
Operating lease, other current liabilities	68	50
Operating lease, deferred credits and other	734	325
Total lease liabilities	802	375
Finance lease, current portion of long-term debt and finance leases	42	41
Long-term debt and finance leases	1,163	1,192
Total finance leases	1,205	1,233
Total lease liabilities	$ 2,007	$ 1,608
Operating lease, weighted-average remaining lease term	12 years	10 years
Finance lease, weighted-average remaining lease term	15 years	16 years
Operating lease, weighted-average discount rate (as a percent)	5.06%	4.52%
Finance lease, weighted-average discount rate (as a percent)	14.11%	14.18%
SDG&E | Purchased-Power Agreements
Lessee, Lease, Description [Line Items]
Variable payments, year one	$ 79
Variable payments, due year five	80
Thereafter	440
Operating lease, other current liabilities	43	$ 18
Operating lease, deferred credits and other	$ 627	$ 208
Operating lease, weighted-average discount rate (as a percent)	5.04%	4.19%
SoCalGas
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 18	$ 29
Finance leases, property plant and equipment	200	173
Finance leases, accumulated depreciation	(90)	(66)
Finance leases, property plant and equipment, net	110	107
Total ROU assets	128	136
Operating lease, other current liabilities	8	10
Operating lease, deferred credits and other	9	18
Total lease liabilities	17	28
Finance lease, current portion of long-term debt and finance leases	23	23
Long-term debt and finance leases	87	84
Total finance leases	110	107
Total lease liabilities	$ 127	$ 135
Operating lease, weighted-average remaining lease term	2 years	3 years
Finance lease, weighted-average remaining lease term	6 years	6 years
Operating lease, weighted-average discount rate (as a percent)	4.70%	4.54%
Finance lease, weighted-average discount rate (as a percent)	5.35%	4.94%
SDG&E
Lessee, Lease, Description [Line Items]
Variable payments, year one	$ 296
Variable payments, due year two	290
Variable payments, due year three	289
Variable payments, due year four	290
Variable payments, due year five	289
Thereafter	$ 1,900
SDG&E | Other Operating Leases
Lessee, Lease, Description [Line Items]
Operating lease, weighted-average discount rate (as a percent)	5.23%	5.06%
Maximum
Lessee, Lease, Description [Line Items]
Operating lease renewal period	25 years
Annual increase in rent, percent	5%
Minimum
Lessee, Lease, Description [Line Items]
Operating lease termination period	1 year
Annual increase in rent, percent	2%

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - LEASE INCOME STATEMENT INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 118	$ 99	$ 83
Amortization of ROU assets	65	60	48
Interest on lease liabilities	178	182	184
Total finance lease costs	243	242	232
Short-term lease costs	9	9	3
Variable lease costs	472	458	411
Total lease costs	842	808	729
Purchased-Power Agreements
Lessee, Lease, Description [Line Items]
Operating lease costs	37	21	10
Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	30	29	25
SDG&E
Lessee, Lease, Description [Line Items]
Operating lease costs	71	53	45
Amortization of ROU assets	42	40	33
Interest on lease liabilities	173	177	181
Total finance lease costs	215	217	214
Short-term lease costs	8	8	2
Variable lease costs	460	447	399
Total lease costs	754	725	660
SDG&E | Purchased-Power Agreements
Lessee, Lease, Description [Line Items]
Operating lease costs	37	21	10
SDG&E | Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	29	28	24
SoCalGas
Lessee, Lease, Description [Line Items]
Operating lease costs	12	13	18
Amortization of ROU assets	23	20	15
Interest on lease liabilities	6	5	2
Total finance lease costs	29	25	17
Short-term lease costs	0	0	0
Variable lease costs	10	10	11
Total lease costs	51	48	46
SoCalGas | Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	$ 1	$ 1	$ 1

COMMITMENTS AND CONTINGENCIES_6

COMMITMENTS AND CONTINGENCIES - LEASES CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 112	$ 85	$ 88
Cash paid for finance leases	163	167	169
Cash paid for finance leases	66	60	48
Increase in operating lease obligations for ROU assets	520	143	142
Increase in finance lease obligations capitalized to PP&E	41	57	57
SDG&E
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	70	46	45
Cash paid for finance leases	158	162	166
Cash paid for finance leases	42	40	33
Increase in operating lease obligations for ROU assets	474	134	134
Increase in finance lease obligations capitalized to PP&E	14	17	16
SoCalGas
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	12	13	18
Cash paid for finance leases	6	5	2
Cash paid for finance leases	24	20	15
Increase in operating lease obligations for ROU assets	0	0	1
Increase in finance lease obligations capitalized to PP&E	$ 27	$ 40	$ 41

COMMITMENTS AND CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY ANALYSIS OF LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Operating leases
2025	$ 142
2026	142
2027	134
2028	128
2029	124
Thereafter	966
Total undiscounted lease payments	1,636
Less: imputed interest	(526)
Total lease liabilities	1,110	$ 669
Less: current lease liabilities	(91)	(70)
Long-term lease liabilities	1,019	599
Finance leases
2025	224
2026	220
2027	218
2028	212
2029	204
Thereafter	1,745
Total undiscounted lease payments	2,823
Less: imputed interest	(1,508)
Total finance leases	1,315	1,340
Less: current lease liabilities	(65)	(64)
Long-term debt and finance leases	1,250	1,276
Purchased-Power Agreements
Operating leases
2025	76
2026	75
2027	76
2028	75
2029	75
Thereafter	525
Less: current lease liabilities	(43)	(18)
Long-term lease liabilities	627	208
SDG&E
Operating leases
2025	97
2026	98
2027	97
2028	92
2029	89
Thereafter	571
Total undiscounted lease payments	1,044
Less: imputed interest	(242)
Total lease liabilities	802	375
Less: current lease liabilities	(68)	(50)
Long-term lease liabilities	734	325
Finance leases
2025	196
2026	195
2027	194
2028	193
2029	190
Thereafter	1,727
Total undiscounted lease payments	2,695
Less: imputed interest	(1,490)
Total finance leases	1,205	1,233
Less: current lease liabilities	(42)	(41)
Long-term debt and finance leases	1,163	1,192
SDG&E | Purchased-Power Agreements
Operating leases
2025	76
2026	75
2027	76
2028	75
2029	75
Thereafter	525
Less: current lease liabilities	(43)	(18)
Long-term lease liabilities	627	208
SoCalGas
Operating leases
2025	10
2026	7
2027	0
2028	0
2029	0
Thereafter	0
Total undiscounted lease payments	17
Less: imputed interest	0
Total lease liabilities	17	28
Less: current lease liabilities	(8)	(10)
Long-term lease liabilities	9	18
Finance leases
2025	28
2026	25
2027	24
2028	19
2029	14
Thereafter	18
Total undiscounted lease payments	128
Less: imputed interest	(18)
Total finance leases	110	107
Less: current lease liabilities	(23)	(23)
Long-term debt and finance leases	$ 87	$ 84

COMMITMENTS AND CONTINGENCIES_8

COMMITMENTS AND CONTINGENCIES - LEASES THAT HAVE NOT YET COMMENCED (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) agreement
Lease Agreement For Tugboat Services | Sempra Infrastructure
Lessee, Lease, Description [Line Items]
2027	$ 10
2028	12
2029	12
Thereafter	198
Estimated payments	$ 184
SDG&E | Purchased-Power Contracts
Lessee, Lease, Description [Line Items]
Lessee, number of purchased-power contracts | agreement	4
Number of purchased-power contracts to be commenced, year one | agreement	2
Number of purchased-power contracts to be commenced, year two | agreement	2
2025	$ 16
2026	41
2027	43
2028	43
2029	43
Thereafter	459
SoCalGas | Headquarters Lease Agreement
Lessee, Lease, Description [Line Items]
2028	8
2029	9
Thereafter	134
Prepaid Expense	$ 1

COMMITMENTS AND CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessor, Lease, Description [Line Items]
Property, plant and equipment, gross	$ 80,397	$ 72,495
Accumulated depreciation	(18,960)	(17,535)
Operating leases
2025	318
2026	272
2027	269
2028	268
2029	246
Thereafter	2,324
Total undiscounted cash flows	3,697
Fixed lease payments	340	321	$ 290
Variable lease payments	38	34	10
Total revenues from operating leases	$ 378	355	300
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration]	Unregulated Operating Revenue
Depreciation expense	$ 2,409	2,202	1,995
Sales-type leases
2025	17
2026	9
2027	0
2028	0
2029	0
Thereafter	0
Total undiscounted cash flows	26
Less: present value of lease payments (recognized as lease receivable)	(23)
Difference between undiscounted cash flows and discounted cash flows	3
Interest income	5	6	8
Total revenues from sales-type lease	5	6	8
Other Current Assets
Sales-type leases
Less: present value of lease payments (recognized as lease receivable)	(15)
Other long-term assets
Sales-type leases
Less: present value of lease payments (recognized as lease receivable)	(8)
Pipelines and storage
Lessor, Lease, Description [Line Items]
Property, plant and equipment, gross	1,313	1,304
Refined products terminals
Lessor, Lease, Description [Line Items]
Property, plant and equipment, gross	623	621
Other
Lessor, Lease, Description [Line Items]
Property, plant and equipment, gross	77	77
Lease assets
Lessor, Lease, Description [Line Items]
Property, plant and equipment, gross	2,013	2,002
Accumulated depreciation	(605)	(539)
Property, plant and equipment, net	1,408	1,463
Operating leases
Depreciation expense	$ 73	$ 62	$ 54

COMMITMENTS AND CONTINGENCIE_10

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Storage and transportation
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	$ 229
2026	225
2027	203
2028	155
2029	140
Thereafter	1,283
Total minimum payments	2,235
Natural Gas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	65
2026	175
2027	271
2028	242
2029	152
Thereafter	212
Total minimum payments	1,117
Natural Gas | SoCalGas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	61
2026	108
2027	124
2028	83
2029	0
Thereafter	0
Total minimum payments	376
Natural Gas Contracts
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	294
2026	400
2027	474
2028	397
2029	292
Thereafter	1,495
Total minimum payments	3,352
Payments	1,185	$ 4,030	$ 2,536
Natural Gas Contracts | SoCalGas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	191
2026	233
2027	228
2028	154
2029	59
Thereafter	118
Total minimum payments	983
Payments	1,088	3,857	2,492
Transportation | SoCalGas
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	130
2026	125
2027	104
2028	71
2029	59
Thereafter	118
Total minimum payments	607
Liquefied Natural Gas Contracts | Sempra Infrastructure
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	355
2026	640
2027	657
2028	646
2029	402
Total minimum payments	2,700
Payments	23	30	108
Purchased-Power Agreements
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Payments	326	325	297
Purchased-Power Agreements | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	97
2026	116
2027	114
2028	114
2029	114
Thereafter	746
Total minimum payments	1,301
2025	79
2026	79
2027	80
2028	80
2029	80
Thereafter	440
Payments	326	$ 325	$ 297
Infrastructure Construction And Improvements | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2025	115
2026	1
2027	1
2028	1
2029	2
Thereafter	13
Construction projects, payable	133
Infrastructure Improvements For Natural Gas And Electric Transmission And Distribution | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	14
Nuclear Plant Maintenance | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	19
Construction Supply Agreements | SDG&E
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	$ 100

COMMITMENTS AND CONTINGENCIE_11

COMMITMENTS AND CONTINGENCIES - OTHER COMMITMENTS (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2021	Dec. 31, 2024 USD ($)	Dec. 31, 2011 $ / MMBTU MMcf
Natural Gas and Electric Franchise | SDG&E
Loss Contingencies [Line Items]
Expected payment		$ 14
Expected payment, due in second year		4
Expected payment, due in third year		2
Expected payment, due in fourth year		2
Expected payment, due in fifth year		2
Expected payment, thereafter		45
Franchise agreements term	20 years
Initial period franchise agreement term	10 years
Renewal portion of franchise agreement term	10 years
Sunrise Powerlink Construction | SDG&E
Loss Contingencies [Line Items]
Expected payment		4
Expected payment, due in second year		4
Expected payment, due in third year		4
Expected payment, due in fourth year		4
Expected payment, due in fifth year		4
Expected payment, thereafter		$ 264
Estimated annual escalation		2%
Present value of future payments		$ 124
Continental Forge | Sempra Infrastructure
Loss Contingencies [Line Items]
Purchase commitment period			18 years
Amount of natural gas to be sold (MMcf per day) | MMcf			500
Price index | $ / MMBTU			0.02

COMMITMENTS AND CONTINGENCIE_12

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) site	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Environmental Issues [Line Items]
Potential monetary sanctions threshold, percentage	1%
Potential monetary sanctions threshold, actual amount	$ 53
Capital expenditures for environmental issues	65	$ 107	$ 87
Accrued liability for environmental matters, discount	$ 14
Accrued liability for environmental matters, discount rate (as a percent)	2.45%
Accrual for environmental loss contingencies	$ 54
Accrual for environmental loss contingencies, current	6
Accrual for environmental loss contingencies, noncurrent	$ 48
Environmental Loss Contingency, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Liabilities, Other than Long-Term Debt, Noncurrent
Expected future payments for accruals, year one	$ 6
Expected future payments for accruals, year two	4
Expected future payments for accruals, year three	8
Expected future payments for accruals, year four	24
Expected future payments for accruals, year five	1
Expected future payments for accruals, thereafter	14
Minimum
Environmental Issues [Line Items]
Potential monetary sanctions threshold	1
SDG&E
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	13
Capital expenditures for environmental issues	23	29	31
Accrual for environmental loss contingencies	16
Accrual for environmental loss contingencies, noncurrent	15
SoCalGas
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	16
Capital expenditures for environmental issues	42	$ 78	$ 56
Accrued liability for environmental matters, discount	$ 14
Accrued liability for environmental matters, discount rate (as a percent)	2.45%
Accrual for environmental loss contingencies	$ 38
Accrual for environmental loss contingencies, current	5
Accrual for environmental loss contingencies, noncurrent	33
SDG&E and SoCalGas
Environmental Issues [Line Items]
Accrual for environmental loss contingencies, current	1
Manufactured-gas sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 34
Manufactured-gas sites | SDG&E
Environmental Issues [Line Items]
Number of sites complete | site	3
Number of sites in process | site	0
Accrual for environmental loss contingencies	$ 0
Manufactured-gas sites | SoCalGas
Environmental Issues [Line Items]
Number of sites complete | site	39
Number of sites in process | site	3
Accrual for environmental loss contingencies	$ 34
Waste Disposal Sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 8
Waste Disposal Sites | SDG&E
Environmental Issues [Line Items]
Number of sites complete | site	2
Number of sites in process | site	1
Accrual for environmental loss contingencies	$ 5
Waste Disposal Sites | SoCalGas
Environmental Issues [Line Items]
Number of sites complete | site	5
Number of sites in process | site	2
Accrual for environmental loss contingencies	$ 3
Other hazardous waste sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	12
Other hazardous waste sites | SDG&E
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	11
Other hazardous waste sites | SoCalGas
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
SONGS Sites | SDG&E
Environmental Issues [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	154
SONGS mitigation costs incurred	56
SONGS mitigation costs remaining	$ 98

SEGMENT INFORMATION - Narrative

SEGMENT INFORMATION - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) segment	Dec. 31, 2023 USD ($)
Segment Reporting Information [Line Items]
Number of operating segments	3
Number of reportable segments	3
Total assets | $	$ 96,155	$ 87,181
SI Partners | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	70%
Oncor Electric Delivery Company LLC | Sempra Texas Utilities
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	80.25%
SDG&E
Segment Reporting Information [Line Items]
Number of operating segments	1
Number of reportable segments	1
SoCalGas
Segment Reporting Information [Line Items]
Number of operating segments	1
Number of reportable segments	1
Total assets | $	$ 25,358	$ 24,266

SEGMENT INFORMATION - Schedule

SEGMENT INFORMATION - Schedule of Segment Information Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	$ 96,155	$ 87,181
Equity method investments	17,933	16,509
Long-lived assets	61,437	54,960
United States
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	52,952	46,935
Mexico
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	8,485	8,024
Rest of the world
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	0	1
Sempra Texas Utilities
Revenues from External Customers and Long-Lived Assets [Line Items]
Equity method investments	15,522	14,380
Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
Equity method investments	2,411	2,129
Operating Segments
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	94,604	87,252
Operating Segments | Sempra California
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	56,116	53,430
Operating Segments | Sempra Texas Utilities
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	15,534	14,392
Operating Segments | Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	22,954	19,430
Parent and other
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	2,622	967
Intersegment revenues
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	$ (1,071)	$ (1,038)

SEGMENT INFORMATION - Schedul_2

SEGMENT INFORMATION - Schedule of Segment Information Income Statement and Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues from External Customers and Long-Lived Assets [Line Items]
CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT	$ 8,215	$ 8,397	$ 5,357
Revenues	13,185	16,720	14,439
Interest income	61	89	75
Interest expense	(1,049)	(1,309)	(1,054)
Income tax expense	(219)	(490)	(556)
Equity earnings	1,609	1,481	1,498
Earnings attributable to noncontrolling interests	(638)	(543)	(146)
Earnings attributable to common shares	2,817	3,030	2,094
United States
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	11,623	14,973	13,015
Mexico
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	1,562	1,747	1,424
Operating Segments
Revenues from External Customers and Long-Lived Assets [Line Items]
CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT	8,212	8,392	5,350
Earnings attributable to common shares	3,538	3,318	2,560
Operating Segments | Sempra California
Revenues from External Customers and Long-Lived Assets [Line Items]
CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT	4,753	4,560	4,466
Revenues	11,382	13,761	12,577
Depreciation and amortization	(2,133)	(1,937)	(1,743)
Interest income	14	24	11
Interest expense	(848)	(782)	(647)
Income tax expense	(184)	31	(320)
Equity earnings	0	0	0
Earnings attributable to noncontrolling interests	0	0	0
Other segment items	(6,385)	(9,350)	(8,364)
Earnings attributable to common shares	1,846	1,747	1,514
Operating Segments | Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT	3,459	3,832	884
Revenues	1,882	3,071	1,919
Depreciation and amortization	(297)	(281)	(268)
Interest income	25	43	44
Interest expense	243	(129)	(104)
Income tax expense	164	(673)	(249)
Equity earnings	802	740	756
Earnings attributable to noncontrolling interests	(638)	(543)	(146)
Other segment items	(1,270)	(1,351)	(1,642)
Earnings attributable to common shares	911	877	310
Operating Segments | Sempra Texas Utilities
Revenues from External Customers and Long-Lived Assets [Line Items]
Equity earnings	788	701	742
Earnings attributable to noncontrolling interests	0	0	0
Other segment items	(7)	(7)	(6)
Earnings attributable to common shares	781	694	736
Parent and other
Revenues from External Customers and Long-Lived Assets [Line Items]
CAPITAL EXPENDITURES FOR PROPERTY, PLANT AND EQUIPMENT	3	5	7
Earnings attributable to common shares	$ (721)	$ (288)	$ (466)

SEGMENT INFORMATION - Revenue B

SEGMENT INFORMATION - Revenue By Services (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues from External Customers and Long-Lived Assets [Line Items]
Energy-related businesses	$ 1,748	$ 2,891	$ 1,788
Revenues from contracts with customers	11,818	14,848	13,722
Revenues	13,185	16,720	14,439
Total assets	96,155	87,181
Operating Segments After Reconciling Items And Eliminations
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from contracts with customers	11,818	14,849	13,723
Total other revenues	1,367	1,871	716
Operating Segments After Reconciling Items And Eliminations | Sempra California
Revenues from External Customers and Long-Lived Assets [Line Items]
Operating Revenue	10,985	13,668	11,930
Energy-related businesses	0	0	0
Revenues from contracts with customers	10,985	13,668	11,930
Utilities	374	75	633
Energy-related businesses	0	0	0
Total other revenues	374	75	633
Operating Segments After Reconciling Items And Eliminations | Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
Operating Revenue	78	87	89
Energy-related businesses	755	1,094	1,704
Revenues from contracts with customers	833	1,181	1,793
Utilities	0	0	0
Energy-related businesses	993	1,796	83
Total other revenues	993	1,796	83
Operating Segments
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	13,264	16,832	14,496
Total assets	94,604	87,252
Operating Segments | Sempra California
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from contracts with customers	11,008	13,686	11,944
Revenues	11,382	13,761	12,577
Total assets	56,116	53,430
Operating Segments | Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from contracts with customers	896	1,251	1,849
Revenues	1,882	3,071	1,919
Total assets	22,954	19,430
Intersegment revenues
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	(79)	(112)	(57)
Total assets	(1,071)	(1,038)
Intersegment revenues | Sempra California
Revenues from External Customers and Long-Lived Assets [Line Items]
Operating Revenue	(23)	(18)	(14)
Energy-related businesses	0	0	0
Revenues	(23)	(18)	(14)
Intersegment revenues | Sempra Infrastructure
Revenues from External Customers and Long-Lived Assets [Line Items]
Operating Revenue	0	0	0
Energy-related businesses	(56)	(94)	(43)
Revenues	$ (56)	$ (94)	$ (43)

SEGMENT INFORMATION - Reconcili

SEGMENT INFORMATION - Reconciliation of Earnings Attributable To Common Shares (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting, Revenue Reconciling Item [Line Items]
Electric	$ 4,296	$ 4,334	$ 4,783
Natural gas	7,141	9,495	7,868
Revenues from contracts with customers	11,818	14,848	13,722
Utilities regulatory revenues	374	75	633
Aliso Canyon litigation and regulatory matters	0	0	(259)
Interest income	61	89	75
Interest expense	(1,049)	(1,309)	(1,054)
Income tax expense	(219)	(490)	(556)
Earnings attributable to common shares	2,817	3,030	2,094
Capital expenditures for property, plant and equipment	8,215	8,397	5,357
SDG&E
Segment Reporting, Revenue Reconciling Item [Line Items]
Electric	4,313	4,349	4,795
Natural gas	1,028	1,248	1,043
Revenues from contracts with customers	5,042	5,954	5,586
Utilities regulatory revenues	299	(357)	252
Operating Revenue	5,341	5,597	5,838
Depreciation and amortization	(1,223)	(1,098)	(982)
Interest income	5	15	5
Interest expense	(525)	(497)	(449)
Income tax expense	(153)	26	(182)
Earnings attributable to common shares	891	936	915
SDG&E | Reportable Segment
Segment Reporting, Revenue Reconciling Item [Line Items]
Electric	4,164	4,750	4,687
Natural gas	878	1,204	899
Revenues from contracts with customers	5,042	5,954	5,586
Funds received on behalf of customers	299	(357)	252
Operating Revenue	5,341	5,597	5,838
Depreciation and amortization	(1,223)	(1,098)	(982)
Interest income	5	15	5
Interest expense	(525)	(497)	(449)
Income tax expense	(153)	26	(182)
Other segment items	(2,554)	(3,107)	(3,315)
Earnings attributable to common shares	891	936	915
Capital expenditures for property, plant and equipment	2,522	2,540	2,473
SDG&E | Natural Gas | Reportable Segment
Segment Reporting, Revenue Reconciling Item [Line Items]
Utilities	150	44	143
SDG&E | Electric, Non-Nuclear | Reportable Segment
Segment Reporting, Revenue Reconciling Item [Line Items]
Utilities	149	(401)	109
SoCalGas
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues from contracts with customers	6,134	7,857	6,459
Utilities regulatory revenues	75	432	381
Operating Revenue	6,209	8,289	6,840
Aliso Canyon litigation and regulatory matters	0	0	(259)
Depreciation and amortization	(910)	(839)	(761)
Interest income	9	9	6
Interest expense	(323)	(285)	(198)
Income tax expense	(31)	5	(138)
Earnings attributable to common shares	955	811	599
SoCalGas | Reportable Segment
Segment Reporting, Revenue Reconciling Item [Line Items]
Natural gas	6,134	7,857	6,459
Funds received on behalf of customers	75	432	381
Operating Revenue	6,209	8,289	6,840
Aliso Canyon litigation and regulatory matters	0	0	(259)
Depreciation and amortization	(910)	(839)	(761)
Interest income	9	9	6
Interest expense	(323)	(285)	(198)
Income tax expense	(31)	5	(138)
Other segment items	(3,999)	(6,368)	(4,891)
Earnings attributable to common shares	955	811	599
Capital expenditures for property, plant and equipment	$ 2,231	$ 2,020	$ 1,993

SCHEDULE I - CONDENSED FINANC_3

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF OPERATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Condensed Income Statements, Captions [Line Items]
Interest income	$ 61	$ 89	$ 75
Interest expense	(1,049)	(1,309)	(1,054)
Other income (expense), net	136	131	24
Income tax expense	(219)	(490)	(556)
Net income	3,500	3,618	2,285
Earnings attributable to common shares	$ 2,817	$ 3,030	$ 2,094
Basic earnings per common share (usd per share)	$ 4.44	$ 4.81	$ 3.32
Weighted-average number of shares outstanding (in shares)	633,795	630,296	630,318
Diluted earnings per common share (usd per share)	$ 4.42	$ 4.79	$ 3.31
Weighted-average number of shares outstanding, diluted (in shares)	637,943	632,733	632,757
Parent Company
Condensed Income Statements, Captions [Line Items]
Interest income	$ 29	$ 31	$ 35
Interest expense	(490)	(444)	(326)
Operating expenses	(105)	(101)	(92)
Other income (expense), net	25	31	(58)
Income tax expense	165	134	111
Income (loss) from continuing operations, net of tax	(376)	(349)	(330)
Equity in earnings of subsidiaries, net of income taxes	3,237	3,423	2,468
Net income	2,861	3,074	2,138
Preferred dividends	(44)	(44)	(44)
Earnings attributable to common shares	$ 2,817	$ 3,030	$ 2,094
Basic earnings per common share (usd per share)	$ 4.44	$ 4.81	$ 3.32
Weighted-average number of shares outstanding (in shares)	633,795	630,296	630,318
Diluted earnings per common share (usd per share)	$ 4.42	$ 4.79	$ 3.31
Weighted-average number of shares outstanding, diluted (in shares)	637,943	632,733	632,757

SCHEDULE I - CONDENSED FINANC_4

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Condensed Statement of Income Captions [Line Items]
Net income, pretax amount, attributable to parent	$ 3,081	$ 3,565	$ 2,695
Income tax (expense) benefit	(219)	(490)	(556)
Total, net of income tax and after NCI	2,862	3,075	2,139
Foreign currency translation adjustments, pretax amount, attributable to parent	(30)	23	11
Foreign currency translation adjustments, income tax (expense) benefit, attributable to parent	0	0	0
Foreign currency translation adjustments, net of tax amount, attributable to parent	(30)	23	11
Financial instruments, pretax amount, attributable to parent	14	57	221
Financial instruments, income tax (expense) benefit, attributable to parent	(2)	(18)	(55)
Financial instruments, net of tax amount, attributable to parent	12	39	166
Pension and other postretirement benefits, pretax amount, attributable to parent	18	(39)	3
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(16)	8	(6)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	(31)	(3)
Total other comprehensive income, pretax amount, attributable to parent	2	41	235
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(18)	(10)	(61)
Total other comprehensive income, net of tax amount, attributable to parent	(16)	31	174
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	3,082	3,605	2,929
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	(237)	(500)	(617)
Comprehensive income, after preferred dividends of subsidiary	2,845	3,105	2,312
Parent Company
Condensed Statement of Income Captions [Line Items]
Net income, pretax amount, attributable to parent	2,696	2,940	2,027
Income tax (expense) benefit	165	134	111
Total, net of income tax and after NCI	2,861	3,074	2,138
Foreign currency translation adjustments, pretax amount, attributable to parent	(30)	23	11
Foreign currency translation adjustments, income tax (expense) benefit, attributable to parent	0	0	0
Foreign currency translation adjustments, net of tax amount, attributable to parent	(30)	23	11
Financial instruments, pretax amount, attributable to parent	14	57	221
Financial instruments, income tax (expense) benefit, attributable to parent	(2)	(18)	(55)
Financial instruments, net of tax amount, attributable to parent	12	39	166
Pension and other postretirement benefits, pretax amount, attributable to parent	18	(39)	3
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(16)	8	(6)
Pension and other postretirement benefits, net of tax amount, attributable to parent	2	(31)	(3)
Total other comprehensive income, pretax amount, attributable to parent	2	41	235
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(18)	(10)	(61)
Total other comprehensive income, net of tax amount, attributable to parent	(16)	31	174
Comprehensive income, after preferred dividends of subsidiary, pretax amount, attributable to parent	2,698	2,981	2,262
Comprehensive income, after preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	147	124	50
Comprehensive income, after preferred dividends of subsidiary	$ 2,845	$ 3,105	$ 2,312

SCHEDULE I - CONDENSED FINANC_5

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
ASSETS
Cash and cash equivalents	$ 1,565	$ 236
Due from affiliates	13	31
Income taxes receivable, net	90	94
Other current assets	34	56
Total current assets	5,285	5,470
Investments in subsidiaries	17,933	16,509
Deferred income taxes	172	129
Other long-term assets	1,749	1,603
Total assets	96,155	87,181
Liabilities and shareholders’ equity:
Short-term debt	2,016	2,342
Total current liabilities	9,676	10,090
Long-term debt	31,558	27,759
Deferred income taxes	5,845	5,254
Other long-term liabilities	352	307
Commitments and contingencies
Total shareholders’ equity	31,222	28,675
Total liabilities and shareholders’ equity	96,155	87,181
Related Party
ASSETS
Due from affiliates	13	31
Liabilities and shareholders’ equity:
Other current liabilities	0	5
Other long-term liabilities	352	307
Nonrelated Party
Liabilities and shareholders’ equity:
Other current liabilities	1,251	1,374
Parent Company
ASSETS
Cash and cash equivalents	1,416	3
Restricted cash	2	2
Due from affiliates	88	105
Income taxes receivable, net	71	0
Other current assets	10	11
Total current assets	1,587	121
Investments in subsidiaries	42,305	38,499
Due from affiliates	25	18
Deferred income taxes	209	429
Other long-term assets	1,152	1,095
Total assets	45,278	40,162
Liabilities and shareholders’ equity:
Short-term debt	0	365
Other current liabilities	1,410	819
Total current liabilities	1,651	1,419
Long-term debt	11,028	8,461
Other long-term liabilities	638	619
Commitments and contingencies
Total shareholders’ equity	31,222	28,675
Total liabilities and shareholders’ equity	45,278	40,162
Parent Company | Related Party
Liabilities and shareholders’ equity:
Other current liabilities	241	235
Long-term debt	$ 739	$ 988

SCHEDULE I - CONDENSED FINANC_6

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - CASH FLOWS (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities		$ 4,907	$ 6,218	$ 1,142
Expenditures for property, plant and equipment		(8,215)	(8,397)	(5,357)
Distributions from investments		1,093	912	854
Net cash used in investing activities		(9,118)	(8,716)	(5,039)
Common dividends paid		(1,499)	(1,483)	(1,430)
Preferred dividends paid		(44)	(44)	(44)
Issuances of common stock, net	$ 144	1,219	145	4
Repurchases of common stock		(43)	(32)	(478)
Issuances of debt (maturities greater than 90 days)		8,674	7,669	9,984
(Decrease) increase in short-term debt, net		(557)	552	(1,266)
Other		(56)	(85)	(35)
Net cash provided by financing activities		5,424	2,419	3,779
Effect of exchange rate changes on cash, cash equivalents and restricted cash		(13)	6	(1)
Increase (decrease) in cash, cash equivalents and restricted cash		1,200	(73)	(119)
Cash, cash equivalents and restricted cash, January 1		389	462	581
Cash, cash equivalents and restricted cash, December 31		1,589	389	462
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued interest receivable capitalized to note receivable		17	16	16
Common dividends issued in stock		54	0	0
Net exercise of stock options		9	0	0
Common Stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends payable		393	376	360
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends payable		11	11	11
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities		120	1,576	775
Expenditures for property, plant and equipment		(3)	(5)	(7)
Proceeds from sale of assets		0	2	0
Capital contributions to investees		(933)	(1,749)	(661)
Distributions from investments		9	108	0
Purchases of trust assets		(63)	(78)	(114)
Proceeds from sales of trust assets		68	69	123
Increase in loans to affiliates, net		(117)	(90)	(92)
Payment to Acquire Life Insurance Policy		(1)	(1)	(3)
Net cash used in investing activities		(1,040)	(1,744)	(754)
Common dividends paid		(1,499)	(1,483)	(1,430)
Preferred dividends paid		(44)	(44)	(44)
Issuances of common stock, net		1,219	145	4
Repurchases of common stock		(43)	(32)	(478)
Issuances of debt (maturities greater than 90 days)		3,695	1,918	1,569
Payments on debt (maturities greater than 90 days)		(350)	(672)	(322)
(Decrease) increase in short-term debt, net		(365)	(89)	(785)
(Decrease) increase in loans from affiliates, net		(241)	220	(226)
Proceeds from sales of noncontrolling interests, net		0	0	1,732
Other		(38)	(10)	(8)
Net cash provided by financing activities		2,334	(47)	12
Effect of exchange rate changes on cash, cash equivalents and restricted cash		(1)	0	(1)
Increase (decrease) in cash, cash equivalents and restricted cash		1,413	(215)	32
Cash, cash equivalents and restricted cash, January 1		5	220	188
Cash, cash equivalents and restricted cash, December 31		1,418	5	220
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued interest receivable capitalized to note receivable		17	16	18
Common dividends issued in stock		54	0	0
Net exercise of stock options		9	0	0
Equitization of amounts due from affiliates		110	92	93
Parent Company | Common Stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends payable		393	376	360
Parent Company | Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends payable		$ 11	$ 11	$ 11

SCHEDULE I - CONDENSED FINANC_7

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - FOOTNOTES (Details)	1 Months Ended				12 Months Ended
	Nov. 30, 2024 USD ($)	Sep. 30, 2024 USD ($)	May 31, 2024 USD ($)	Mar. 31, 2024 USD ($) business_day	Dec. 31, 2024 USD ($) lender	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Debt Instruments [Abstract]
Maximum borrowing capacity					$ 9,900,000,000
Committed lines of credit, capacity for issuance of letters of credit					200,000,000
Line of credit, increase limit					500,000,000
Letters of credit outstanding					497,000,000
Gross long-term debt					16,590,000,000	$ 12,207,000,000
Long-term debt					31,558,000,000	27,759,000,000
Long-term debt, maturity, year one					2,212,000,000
Long-term debt, maturity, year two					1,853,000,000
Long-term debt, maturity, year three					1,499,000,000
Long-term debt, maturity, year four					1,963,000,000
Long-term debt, maturity, year five					584,000,000
Thereafter					24,788,000,000
Operating leases
Total operating lease commitments					1,636,000,000
2025					142,000,000
2026					142,000,000
2027					134,000,000
2028					128,000,000
2029					124,000,000
Thereafter					966,000,000
Operating lease costs					$ 118,000,000	$ 99,000,000	$ 83,000,000
Operating lease, weighted-average discount rate (as a percent)					6.10%	6.64%
Maximum ratio of indebtedness to total capitalization					0.65
6.40% Junior Subordinated Notes, Due October 1, 2054
Debt Instruments [Abstract]
Stated percentage rate		6.40%
Parent Company
Basis of Presentation
Cash dividends received					$ 908,000,000	$ 1,900,000,000	832,000,000
Debt Instruments [Abstract]
Maximum borrowing capacity					4,000,000,000
Amount available					$ 4,000,000,000
Number of lenders | lender					23
Share of facility held by lenders (as a percent)					6%
Committed lines of credit, capacity for issuance of letters of credit					$ 200,000,000
Line of credit, increase limit					500,000,000
Letters of credit outstanding					0
Gross long-term debt					11,908,000,000	8,558,000,000
Current portion of long-term debt					(750,000,000)	0
Unamortized discount on long-term debt					(30,000,000)	(29,000,000)
Unamortized debt issuance costs					(100,000,000)	(68,000,000)
Long-term debt					11,028,000,000	8,461,000,000
Long-term debt, maturity, year one					750,000,000
Long-term debt, maturity, year two					550,000,000
Long-term debt, maturity, year three					750,000,000
Long-term debt, maturity, year four					1,000,000,000
Long-term debt, maturity, year five					500,000,000
Thereafter					8,400,000,000
Operating leases
Total operating lease commitments					212,000,000
2025					12,000,000
2026					12,000,000
2027					12,000,000
2029					13,000,000
Thereafter					151,000,000
Operating lease costs					$ 14,000,000	$ 14,000,000	$ 14,000,000
Operating lease, weighted-average discount rate (as a percent)					4.70%	4.70%
Maximum ratio of indebtedness to total capitalization					0.65
Parent Company | Corporate Headquarters
Operating leases
Total operating lease commitments					$ 147,000,000
Parent Company | 3.30% Notes April 1, 2025
Debt Instruments [Abstract]
Stated percentage rate					3.30%
Gross long-term debt					$ 750,000,000	$ 750,000,000
Parent Company | 5.40% Notes August 1, 2026
Debt Instruments [Abstract]
Stated percentage rate					5.40%
Gross long-term debt					$ 550,000,000	550,000,000
Parent Company | 3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate					3.25%
Gross long-term debt					$ 750,000,000	750,000,000
Parent Company | 3.40% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate					3.40%
Gross long-term debt					$ 1,000,000,000	1,000,000,000
Parent Company | 3.70% Notes April 1, 2029
Debt Instruments [Abstract]
Stated percentage rate					3.70%
Gross long-term debt					$ 500,000,000	500,000,000
Parent Company | 5.50% Notes August 1, 2033
Debt Instruments [Abstract]
Gross long-term debt					$ 700,000,000	700,000,000
Parent Company | 3.80% Notes February 1, 2038
Debt Instruments [Abstract]
Stated percentage rate					3.80%
Gross long-term debt					$ 1,000,000,000	1,000,000,000
Parent Company | 6.00% Notes October 15, 2039
Debt Instruments [Abstract]
Stated percentage rate					6%
Gross long-term debt					$ 750,000,000	750,000,000
Parent Company | 4.00% Notes February 1, 2048
Debt Instruments [Abstract]
Stated percentage rate					4%
Gross long-term debt					$ 800,000,000	800,000,000
Parent Company | 4.125% Junior Subordinated Notes April 1, 2052
Debt Instruments [Abstract]
Stated percentage rate					4.125%
Gross long-term debt					$ 1,000,000,000	1,000,000,000
Parent Company | 5.75% Junior Subordinated Notes July 1, 2079
Debt Instruments [Abstract]
Gross long-term debt					$ 758,000,000	758,000,000
Parent Company | Other Long-Term Debt, Due August 2033
Debt Instruments [Abstract]
Stated percentage rate					5.50%
Parent Company | Other Long-Term Debt, 5.75% Junior Subordinated Notes July 1, 2079
Debt Instruments [Abstract]
Stated percentage rate				5.75%	5.75%
Parent Company | Junior Subordinated Notes 6.40% Due 2054
Debt Instruments [Abstract]
Stated percentage rate					6.40%
Gross long-term debt					$ 1,250,000,000	0
Parent Company | Junior Subordinated Notes 6.875% Due 2054
Debt Instruments [Abstract]
Stated percentage rate					6.875%
Gross long-term debt					$ 600,000,000	0
Parent Company | 6.875% Junior Subordinated Notes, Due October 1, 2054
Debt Instruments [Abstract]
Debt amount			$ 500,000,000
Proceeds from issuance of debt			489,000,000
Underwriting discounts and debt issuance costs			11,000,000
Accrued interest			$ 7,000,000
Number of days before interest rate period | business_day				2
Debt instrument, interest rate, period (in years)				5 years
Parent Company | Junior Subordinated Notes 6.875% Due 2054, Number 2
Debt Instruments [Abstract]
Stated percentage rate					6.875%
Gross long-term debt					$ 500,000,000	0
Parent Company | Junior Subordinated Notes 6.55% Due 2055
Debt Instruments [Abstract]
Stated percentage rate					6.55%
Gross long-term debt					$ 600,000,000	0
Parent Company | Junior Subordinated Notes 6.625% Due 2055
Debt Instruments [Abstract]
Stated percentage rate					6.625%
Gross long-term debt					$ 400,000,000	0
Parent Company | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054
Debt Instruments [Abstract]
Stated percentage rate			6.875%	6.875%
Debt amount				$ 600,000,000
Proceeds from issuance of debt				593,000,000
Underwriting discounts and debt issuance costs				$ 7,000,000
Parent Company | 6.40% Junior Subordinated Notes, Due October 1, 2054
Debt Instruments [Abstract]
Stated percentage rate		6.40%
Debt amount		$ 1,250,000,000
Proceeds from issuance of debt		1,235,000,000
Underwriting discounts and debt issuance costs		$ 15,000,000
Variable percentage rate		2.632%
Parent Company | Other Long-Term Debt, 6.625% Junior Subordinated Notes April 1, 2055
Debt Instruments [Abstract]
Stated percentage rate	6.625%
Debt amount	$ 400,000,000
Proceeds from issuance of debt	395,000,000
Underwriting discounts and debt issuance costs	$ 5,000,000
Variable percentage rate	2.354%
Parent Company | Other Long-Term Debt, 6.55% Junior Subordinated Notes April 1, 2055
Debt Instruments [Abstract]
Stated percentage rate	6.55%
Debt amount	$ 600,000,000
Proceeds from issuance of debt	593,000,000
Underwriting discounts and debt issuance costs	$ 7,000,000
Variable percentage rate	2.138%
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)					100%
Parent Company | 6.875% Junior Subordinated Notes, Issued In March and May 2024
Debt Instruments [Abstract]
Variable percentage rate				2.789%
Sempra
Debt Instruments [Abstract]
Maximum borrowing capacity					$ 4,000,000,000
Other Sempra
Debt Instruments [Abstract]
Gross long-term debt					11,908,000,000	8,558,000,000
Unamortized discount on long-term debt					(78,000,000)	(66,000,000)
Unamortized debt issuance costs					(144,000,000)	(112,000,000)
Long-term debt					14,509,000,000	12,018,000,000
Variable percentage rate	2.354%	2.632%
Long-term debt, maturity, year one					1,862,000,000
Long-term debt, maturity, year two					599,000,000
Long-term debt, maturity, year three					799,000,000
Long-term debt, maturity, year four					1,358,000,000
Long-term debt, maturity, year five					584,000,000
Thereafter					$ 11,388,000,000
Other Sempra | 5.50% Senior Unsecured Notes August 1, 2033
Debt Instruments [Abstract]
Stated percentage rate					5.50%
Gross long-term debt					$ 700,000,000	700,000,000
Other Sempra | Other Long-Term Debt, 3.30% Notes April 1, 2025
Debt Instruments [Abstract]
Stated percentage rate					3.30%
Gross long-term debt					$ 750,000,000	750,000,000
Other Sempra | 5.40% Senior Unsecured Notes August 1, 2026
Debt Instruments [Abstract]
Stated percentage rate					5.40%
Gross long-term debt					$ 550,000,000	550,000,000
Other Sempra | Other Long-Term Debt, 3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate					3.25%
Gross long-term debt					$ 750,000,000	750,000,000
Other Sempra | Other Long-Term Debt, 3.40% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate					3.40%
Gross long-term debt					$ 1,000,000,000	1,000,000,000
Other Sempra | Other Long-Term Debt, 3.70% Notes April 1, 2029
Debt Instruments [Abstract]
Stated percentage rate					3.70%
Gross long-term debt					$ 500,000,000	500,000,000
Other Sempra | Other Long-Term Debt, 5.75% Junior Subordinated Notes July 1, 2079
Debt Instruments [Abstract]
Stated percentage rate					5.75%
Gross long-term debt					$ 758,000,000	758,000,000
Other Sempra | 6.875% Junior Subordinated Notes, Due October 1, 2054
Debt Instruments [Abstract]
Debt amount			$ 500,000,000
Proceeds from issuance of debt			489,000,000
Underwriting discounts and debt issuance costs			11,000,000
Accrued interest			$ 7,000,000
Other Sempra | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054
Debt Instruments [Abstract]
Stated percentage rate					6.875%
Gross long-term debt					$ 600,000,000	0
Debt amount				$ 600,000,000
Proceeds from issuance of debt				593,000,000
Underwriting discounts and debt issuance costs				$ 7,000,000
Other Sempra | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054 | Period one
Debt Instruments [Abstract]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)			100%		100%
Other Sempra | Other Long-Term Debt, 6.875% Junior Subordinated Notes October 1, 2054 | Period two
Debt Instruments [Abstract]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)			102%	102%
Other Sempra | 6.40% Junior Subordinated Notes, Due October 1, 2054
Debt Instruments [Abstract]
Debt amount		$ 1,250,000,000
Proceeds from issuance of debt		1,235,000,000
Underwriting discounts and debt issuance costs		$ 15,000,000
Other Sempra | Other Long-Term Debt, 6.625% Junior Subordinated Notes April 1, 2055
Debt Instruments [Abstract]
Stated percentage rate	6.625%				6.625%
Gross long-term debt					$ 400,000,000	0
Debt amount	$ 400,000,000
Proceeds from issuance of debt	395,000,000
Underwriting discounts and debt issuance costs	$ 5,000,000
Other Sempra | Other Long-Term Debt, 6.55% Junior Subordinated Notes April 1, 2055
Debt Instruments [Abstract]
Stated percentage rate	6.55%				6.55%
Gross long-term debt					$ 600,000,000	0
Debt amount	$ 600,000,000
Proceeds from issuance of debt	593,000,000
Underwriting discounts and debt issuance costs	$ 7,000,000
Variable percentage rate	2.138%
Other Sempra | Other Long-Term Debt, 4.125% Junior Subordinated Notes April 1, 2052
Debt Instruments [Abstract]
Stated percentage rate				4.125%	4.125%
Gross long-term debt					$ 1,000,000,000	$ 1,000,000,000
Other Sempra | 6.875% Junior Subordinated Notes, Issued In March and May 2024
Debt Instruments [Abstract]
Variable percentage rate			2.789%