0001032208-23-000043 | 10-Q | XBRL Viewer

1,316

1,194

410

Beginning Balance at Mar. 31, 2022

29,053

12,121

13,998

(167)

8,659

1,660

7,009

(10)

27,560

11,656

13,798

(229)

8,483

1,660

6,833

(10)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

659

571

176

Beginning Balance at Dec. 31, 2022

29,053

12,121

13,998

(167)

8,659

1,660

7,009

(10)

29,256

^[1]

12,160

14,201

(135)

9,067

1,660

7,414

(7)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,908

1,595

442

Beginning Balance at Mar. 31, 2023

31,014

12,044

15,024

(121)

9,509

1,660

7,856

(7)

30,245

12,164

14,796

(182)

9,325

1,660

7,672

(7)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

736

615

184

$ 31,014

$ 12,044

$ 15,024

$ (121)

$ 9,509

$ 1,660

$ 7,856

$ (7)

[1]	Derived from audited financial statements.

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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Amount of equity (deficit) attributable to parent and noncontrolling interest. Excludes temporary equity.

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-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480008/505-10-S99-1

Reference 38: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480678/235-10-S99-1

Reference 39: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 323
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481687/323-10-50-3

Reference 40: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 825
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 28
-Subparagraph (f)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482907/825-10-50-28

Reference 41: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 15
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481231/810-10-45-15

Reference 42: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 16
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481231/810-10-45-16

Reference 43: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4I
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481175/810-10-55-4I

Beginning Balance at Dec. 31, 2021

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

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

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

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($)
$ in Millions

Total

Series C Preferred Stock

Preferred stock

Common stock

Retained earnings

Series C Preferred Stock

Accumulated other comprehensive income (loss)

Sempra shareholders' equity

Series C Preferred Stock

Non- controlling interests

$ 27,419

$ 889

$ 11,862

$ 13,548

$ (318)

$ 25,981

$ 1,438

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,316

1,194

122

178

142

$ (22)

(721)

Issuances of common stock

(1)

Repurchases of common stock

(476)

(106)

Sale

1,418

700

709

Beginning Balance at Mar. 31, 2022

29,053

889

12,121

13,998

(167)

26,841

2,212

27,560

889

11,656

13,798

(229)

26,114

1,446

Increase (Decrease) in Stockholders' Equity [Roll Forward]

659

571

(11)

(359)

Repurchases of common stock

(1)

(250)

(53)

Sale

1,418

700

709

Beginning Balance at Dec. 31, 2022

29,053

889

12,121

13,998

(167)

26,841

2,212

29,256

^[1]

889

12,160

14,201

(135)

27,115

2,141

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,908

1,595

313

(22)

(749)

Repurchases of common stock

(1)

(31)

595

(134)

729

(252)

Sale

255

237

Beginning Balance at Mar. 31, 2023

31,014

889

12,044

15,024

(121)

27,836

3,178

30,245

889

12,164

14,796

(182)

27,667

2,578

Increase (Decrease) in Stockholders' Equity [Roll Forward]

736

615

121

117

$ (11)

(375)

(1)

498

(134)

632

(209)

Recurring Fair Value Measures

$ 31,014

$ 889

$ 12,044

$ 15,024

$ (121)

$ 27,836

$ 3,178

[1]	Derived from audited financial statements.

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

FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	22	$	2	$	—	$	24
Equity securities	318		4		—		322
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	25		14		—		39
Municipal bonds	—		266		—		266
Other securities	—		218		—		218
Total debt securities	25		498		—		523
Total nuclear decommissioning trusts(1)	365		504		—		869
Short-term investments held in Rabbi Trust	51		—		—		51
Interest rate instruments	—		62		—		62
Commodity contracts not subject to rate recovery	—		19		—		19
Effect of netting and allocation of collateral(2)	143		—		—		143
Commodity contracts subject to rate recovery	—		1		20		21
Effect of netting and allocation of collateral(2)	65		—		5		70
Support Agreement, net of related guarantee fees	—		—		23		23
Total	$	624	$	586	$	48	$	1,258
Liabilities:
Interest rate instruments	$	—	$	2	$	—	$	2
Foreign exchange instruments	—		15		—		15
Commodity contracts not subject to rate recovery	—		11		—		11
Commodity contracts subject to rate recovery	14		51		—		65
Effect of netting and allocation of collateral(2)	(14)		—		—		(14)
Total	$	—	$	79	$	—	$	79

(1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SEMPRA (CONTINUED)
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at December 31, 2022
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	10	$	1	$	—	$	11
Equity securities	293		4		—		297
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		13		—		40
Municipal bonds	—		270		—		270
Other securities	—		227		—		227
Total debt securities	27		510		—		537
Total nuclear decommissioning trusts(1)	330		515		—		845
Short-term investments held in Rabbi Trust	55		—		—		55
Interest rate instruments	—		76		—		76
Commodity contracts not subject to rate recovery	—		273		—		273
Effect of netting and allocation of collateral(2)	451		—		—		451
Commodity contracts subject to rate recovery	82		19		35		136
Effect of netting and allocation of collateral(2)	12		—		6		18
Support Agreement, net of related guarantee fees	—		—		17		17
Total	$	930	$	883	$	58	$	1,871
Liabilities:
Foreign exchange instruments	$	—	$	8	$	—	$	8
Interest rate and foreign exchange instruments	—		105		—		105
Commodity contracts not subject to rate recovery	—		191		—		191
Commodity contracts subject to rate recovery	—		70		—		70
Total	$	—	$	374	$	—	$	374

1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	22	$	2	$	—	$	24
Equity securities	318		4		—		322
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	25		14		—		39
Municipal bonds	—		266		—		266
Other securities	—		218		—		218
Total debt securities	25		498		—		523
Total nuclear decommissioning trusts(1)	365		504		—		869
Commodity contracts subject to rate recovery	—		—		20		20
Effect of netting and allocation of collateral(2)	64		—		5		69
Total	$	429	$	504	$	25	$	958
Liabilities:
Commodity contracts subject to rate recovery	$	14	$	5	$	—	$	19
Effect of netting and allocation of collateral(2)	(14)		—		—		(14)
Total	$	—	$	5	$	—	$	5

	Fair value at December 31, 2022
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	10	$	1	$	—	$	11
Equity securities	293		4		—		297
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		13		—		40
Municipal bonds	—		270		—		270
Other securities	—		227		—		227
Total debt securities	27		510		—		537
Total nuclear decommissioning trusts(1)	330		515		—		845
Commodity contracts subject to rate recovery	82		3		35		120
Effect of netting and allocation of collateral(2)	11		—		6		17
Total	$	423	$	518	$	41	$	982
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Total	$	—	$	1	$	—	$	1

(1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	1	$	—	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	46	$	—	$	46
Total	$	—	$	46	$	—	$	46

	Fair value at December 31, 2022
Assets:
Commodity contracts subject to rate recovery	$	—	$	16	$	—	$	16
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	16	$	—	$	17
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	69	$	—	$	69
Total	$	—	$	69	$	—	$	69

(1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

Recurring Fair Value Measures Level 3 Rollforward

The table below sets forth reconciliations of changes in the fair value of CRRs and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra and SDG&E.


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended June 30,
	2023		2022
Balance at April 1	$	30	$	58
Realized and unrealized losses	(4)		(30)
Allocated transmission instruments	(2)		(6)
Settlements	(4)		11
Balance at June 30	$	20	$	33
Change in unrealized losses relating to instruments still held at June 30	$	(7)	$	(23)

	Six months ended June 30,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized losses	(8)		(23)
Allocated transmission instruments	(2)		(6)
Settlements	(5)		8
Balance at June 30	$	20	$	33
Change in unrealized losses relating to instruments still held at June 30	$	(9)	$	(18)

(1) Excludes the effect of the contractual ability to settle contracts under master netting agreements.

The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra.


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2023		2022
Balance at April 1	$	24	$	12
Realized and unrealized gains(1)	1		6
Settlements	(2)		(2)
Balance at June 30(2)	$	23	$	16
Change in unrealized gains relating to instruments still held at June 30	$	1	$	5

	Six months ended June 30,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	10		14
Settlements	(4)		(5)
Balance at June 30(2)	$	23	$	16
Change in unrealized gains relating to instruments still held at June 30	$	9	$	13

(1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Condensed Consolidated Statements of Operations.

(2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet.

Schedule of Fair Value Inputs

For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below:


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

Settlement year	Price per MWh					Median price per MWh
2023	$	(3.09)	to	$	10.71	$	(0.56)
2022	(3.67)		to	6.96		(0.70)

The range and weighted-average price of these inputs at June 30 were as follows:


LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS

Settlement year						Weighted-average price per MWh
2023	$	22.75	to	$	117.50	$	74.02
2022	25.25		to	125.00		66.36

Fair Value of Financial Instruments

The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Condensed Consolidated Balance Sheets.


FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2023
Sempra:

Long-term note receivable(1)	$	326	$	—	$	—	$	296	$	296
Long-term amounts due to unconsolidated affiliates	287		—		251		—		251
Total long-term debt(2)	27,419		—		24,630		—		24,630
SDG&E:
Total long-term debt(3)	$	8,600	$	—	$	7,535	$	—	$	7,535
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	6,270	$	—	$	6,270

	December 31, 2022
Sempra:
Long-term note receivable(1)	$	318	$	—	$	—	$	286	$	286
Long-term amounts due to unconsolidated affiliates	301		—		263		—		263
Total long-term debt(2)	24,513		—		21,549		—		21,549
SDG&E:
Total long-term debt(3)	$	7,800	$	—	$	6,726	$	—	$	6,726
SoCalGas:
Total long-term debt(4)	$	6,059	$	—	$	5,538	$	—	$	5,538

(1) Before allowances for credit losses of $6 and $7 at June 30, 2023 and December 31, 2022, respectively. Excludes unamortized transaction costs of $4 and $5 at June 30, 2023 and December 31, 2022, respectively.

(2) Before reductions of unamortized discount and debt issuance costs of $325 and $289 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,351 and $1,343 at June 30, 2023 and December 31, 2022, respectively.

(3) Before reductions of unamortized discount and debt issuance costs of $85 and $70 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,241 and $1,256 at June 30, 2023 and December 31, 2022, respectively.

(4) Before reductions of unamortized discount and debt issuance costs of $57 and $48 at June 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $110 and $87 at June 30, 2023 and December 31, 2022, respectively.

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

Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Jun. 30, 2023	Dec. 31, 2022
Sempra
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.92%	5.57%
San Diego Gas and Electric Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.00%	4.76%
Southern California Gas Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.14%	4.71%

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended		12 Months Ended	22 Months Ended
	Jul. 31, 2023 plaintiff	Sep. 30, 2021 USD ($) lawsuit plaintiff	Jun. 30, 2023 USD ($) lawsuit	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) lawsuit	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Jul. 31, 2023 plaintiff	Nov. 30, 2021 Bcf	Jan. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 222		$ 222
Natural gas inventory level (in bcf) \| Bcf									41.16
Aliso Canyon litigation and regulatory matters			0	$ 45	0	$ 137
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings			126		126
Southern California Gas Company
Loss Contingencies [Line Items]
Liability for legal proceedings			142		142
Aliso Canyon litigation and regulatory matters			0	45	0	137
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings			126		126
Number of lawsuits \| lawsuit		390
Number of plaintiffs \| plaintiff		36,000
Net book value of Aliso Canyon facility			976		976
Reserve for Aliso Canyon costs			$ 126		$ 126
Aliso Canyon litigation and regulatory matters, net of tax				$ 32		$ 98
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff	243
Southern California Gas Company \| Shareholder Derivative Complaint
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit			4		4					3
Southern California Gas Company \| Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs		$ 1,800
Percentage of plaintiffs agreeing to participate and submit releases (in percent)							99.00%
Payment of liquidating companies' costs							$ 1,790
Southern California Gas Company \| The Developer Plaintiffs \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff								388
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 6		$ 6
Deferred Credits and Other \| Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Reserve for Aliso Canyon costs			$ 2		$ 2

SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

SEGMENT INFORMATION

We have four separately managed reportable segments, as follows:

▪SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County.

▪SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California.

▪Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electricity transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, L.L.C., a regulated electric transmission utility serving customers near the Texas-Mexico border.

▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally.

We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, the FERC.

The cost of common services shared by the business segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of activities of parent organizations.


SEGMENT INFORMATION
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
REVENUES
SDG&E	$	1,262	$	1,399	$	2,915	$	2,844
SoCalGas	1,467		1,501		5,261		3,494
Sempra Infrastructure	660		689		1,856		1,113
Adjustments and eliminations	(2)		(2)		(1)		—
Intersegment revenues(1)	(52)		(40)		(136)		(84)
Total	$	3,335	$	3,547	$	9,895	$	7,367
DEPRECIATION AND AMORTIZATION
SDG&E	$	268	$	244	$	530	$	483
SoCalGas	208		188		414		375
Sempra Infrastructure	70		67		139		132
All other	3		2		5		4
Total	$	549	$	501	$	1,088	$	994
INTEREST INCOME
SDG&E	$	4	$	1	$	5	$	1
SoCalGas	1		1		5		1
Sempra Infrastructure	6		9		21		30
All other	6		4		10		8
Total	$	17	$	15	$	41	$	40
INTEREST EXPENSE
SDG&E	$	123	$	114	$	241	$	220
SoCalGas	71		45		140		85
Sempra Infrastructure	25		32		120		59
All other	99		81		183		151
Intercompany eliminations	(1)		(1)		(1)		(1)
Total	$	317	$	271	$	683	$	514
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	4	$	42	$	11	$	106
SoCalGas	(21)		19		73		103
Sempra Infrastructure	201		70		531		161
All other	(9)		(51)		(64)		44
Total	$	175	$	80	$	551	$	414
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	3	$	3	$	5
Sempra Infrastructure	151		156		282		297

	153		159		285		302
Equity earnings, net of income tax:
Sempra Texas Utilities	160		184		243		346
Sempra Infrastructure	75		32		79		53
	235		216		322		399
Total	$	388	$	375	$	607	$	701

(1) Revenues for reportable segments include intersegment revenues of $5, $28, and $19 for the three months ended June 30, 2023 and $9, $62, and $65 for the six months ended June 30, 2023; $3, $23, and $14 for the three months ended June 30, 2022 and $7, $49, and $28 for the six months ended June 30, 2022 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	184	$	176	$	442	$	410
SoCalGas	155		87		515		421
Sempra Texas Utilities	160		186		243		348
Sempra Infrastructure	208		183		523		278
All other	(104)		(73)		(151)		(286)
Total	$	603	$	559	$	1,572	$	1,171
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,239	$	1,090
SoCalGas					961		931
Sempra Infrastructure					2,078		336
All other					4		4
Total					$	4,282	$	2,361

					June 30, 2023		December 31, 2022
ASSETS
SDG&E					$	27,786	$	26,422
SoCalGas					22,591		22,346
Sempra Texas Utilities					13,988		13,781
Sempra Infrastructure					17,610		15,760
All other					1,773		1,376
Intersegment receivables					(1,021)		(1,111)
Total					$	82,727	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities					$	13,979	$	13,772
Sempra Infrastructure					2,036		1,905
Total					$	16,015	$	15,677

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Revenue from Contract with Customer [Abstract]

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

REVENUES (Tables)

6 Months Ended

Jun. 30, 2023

Schedule of Disaggregation of Revenue

The following table disaggregates our revenues from contracts with customers by major service line and market and provides a reconciliation to total revenues by segment. The majority of our revenue is recognized over time.


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2023
By major service line:
Utilities	$	1,400	$	1,291	$	19	$	(34)	$	2,676
Energy-related businesses	—		—		235		(19)		216
Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892

By market:
Gas	$	252	$	1,291	$	167	$	(30)	$	1,680
Electric	1,148		—		87		(23)		1,212
Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892

Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892
Utilities regulatory revenues	(138)		176		—		—		38
Other revenues	—		—		406		(1)		405
Total revenues	$	1,262	$	1,467	$	660	$	(54)	$	3,335

	Six months ended June 30, 2023
By major service line:
Utilities	$	3,165	$	5,132	$	49	$	(72)	$	8,274
Energy-related businesses	—		—		547		(40)		507
Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781

By market:
Gas	$	806	$	5,132	$	371	$	(65)	$	6,244
Electric	2,359		—		225		(47)		2,537
Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781

Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781
Utilities regulatory revenues	(250)		129		—		—		(121)
Other revenues	—		—		1,260		(25)		1,235
Total revenues	$	2,915	$	5,261	$	1,856	$	(137)	$	9,895


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2022
By major service line:
Utilities	$	1,250	$	1,347	$	20	$	(27)	$	2,590
Energy-related businesses	—		—		457		(14)		443
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033

By market:
Gas	$	159	$	1,347	$	340	$	(19)	$	1,827
Electric	1,091		—		137		(22)		1,206
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033

Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Utilities regulatory revenues	149		154		—		—		303
Other revenues	—		—		212		(1)		211
Total revenues	$	1,399	$	1,501	$	689	$	(42)	$	3,547

	Six months ended June 30, 2022
By major service line:
Utilities	$	2,751	$	3,259	$	48	$	(56)	$	6,002
Energy-related businesses	—		—		749		(29)		720
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722

By market:
Gas	$	489	$	3,259	$	569	$	(45)	$	4,272
Electric	2,262		—		228		(40)		2,450
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722

Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Utilities regulatory revenues	93		235		—		—		328
Other revenues	—		—		316		1		317
Total revenues	$	2,844	$	3,494	$	1,113	$	(84)	$	7,367

Schedule of Timing of Remaining Performance Obligations

For contracts greater than one year, at June 30, 2023, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2023.


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first six months of 2023)	$	175	$	2
2024	300		4
2025	338		4
2026	365		4
2027	365		4
Thereafter	4,077		59
Total revenues to be recognized	$	5,620	$	77

(1) Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2023 or 2022. As we discuss in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report, Sempra Infrastructure drew against and fully exhausted SEFE’s letters of credit in April 2022 due to SEFE’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance.


CONTRACT LIABILITIES
(Dollars in millions)
	2023		2022
Sempra:
Contract liabilities at January 1	$	(252)	$	(278)
Revenue from performance obligations satisfied during reporting period	5		86
Payments received in advance	(2)		(105)
Contract liabilities at June 30(1)	$	(249)	$	(297)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(2)	$	(77)	$	(81)

(1) Balances at June 30, 2023 include $6 in Other Current Liabilities and $243 in Deferred Credits and Other.

(2) Balances at June 30, 2023 include $4 in Other Current Liabilities and $73 in Deferred Credits and Other.

Schedule of Contract Accounts Receivable

The table below shows receivable balances associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets.


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2023		December 31, 2022
Sempra:
Accounts receivable – trade, net(1)	$	1,828	$	2,291
Accounts receivable – other, net	14		25
Due from unconsolidated affiliates – current(2)	7		9
Other long-term assets(3)	3		9
Total	$	1,852	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	813	$	799
Accounts receivable – other, net	10		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	2		6
Total	$	831	$	819
SoCalGas:
Accounts receivable – trade, net	$	856	$	1,295
Accounts receivable – other, net	4		13
Other long-term assets(3)	1		3
Total	$	861	$	1,311

(1) At June 30, 2023 and December 31, 2022, includes $123 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

(2) Amount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists.

(3) In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas enrolled residential and small business customers with past-due balances in long-term repayment plans.

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

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

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA

6 Months Ended

Jun. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

Effective May 12, 2023, our company changed its legal name from Sempra Energy to Sempra. Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities. We have four separate reportable segments, which we discuss in Note 11. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name.

SDG&E

SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra.

SoCalGas

SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra.

BASIS OF PRESENTATION

This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. We have eliminated intercompany accounts and transactions within Sempra’s consolidated financial statements.

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2023 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation.

All December 31, 2022 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2022 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC.

We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes.

The information contained in this report should be read in conjunction with the Annual Report.

Regulated Operations

SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report.

Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas.

Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase.

Restricted cash includes:

▪for Sempra Infrastructure, funds fully drawn against SEFE’s letters of credit, including draws associated with its LNG storage and regasification agreement; funds denominated in U.S. dollars and Mexican pesos to pay for rights-of-way and other costs pursuant to trust agreements related to pipeline projects; and certain funds at Port Arthur LNG for which withdrawals and usage are dictated by its debt agreements

▪for Parent and other, funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Condensed Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Condensed Consolidated Statements of Cash Flows.


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2023		December 31, 2022
Cash and cash equivalents	$	1,077	$	370
Restricted cash, current	74		40
Restricted cash, noncurrent	91		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	1,242	$	462

CREDIT LOSSES

We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in sales-type leases and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 5.

We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered.

In the first quarter of 2022, SDG&E and SoCalGas received $63 million and $79 million, respectively, on behalf of their customers from the California Department of Community Services and Development under the 2021 California Arrearage Payment Program and applied the amounts directly to eligible customer accounts to reduce past due balances. In June 2022, AB 205 was approved establishing, among other things, the 2022 California Arrearage Payment Program. In December 2022, SDG&E and SoCalGas received funding of $51 million and $59 million, respectively, related to this program and, in January 2023, applied the amounts directly to eligible customer accounts to reduce past due balances.

We provide below the changes in allowances for credit losses for trade receivables and other receivables. SDG&E and SoCalGas record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2023		2022
Sempra:
Allowances for credit losses at January 1	$	181	$	136
Provisions for expected credit losses	228		77
Write-offs	(43)		(36)
Allowances for credit losses at June 30	$	366	$	177
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	63		37
Write-offs	(23)		(18)
Allowances for credit losses at June 30	$	118	$	85
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	164		37
Write-offs	(20)		(18)
Allowances for credit losses at June 30	$	242	$	88

Allowances for credit losses related to trade receivables and other receivables are included in the Condensed Consolidated Balance Sheets as follows:


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	320	$	140
Accounts receivable – other, net	46		40
Other long-term assets	—		1
Total allowances for credit losses	$	366	$	181
SDG&E:
Accounts receivable – trade, net	$	91	$	52
Accounts receivable – other, net	27		25
Other long-term assets	—		1
Total allowances for credit losses	$	118	$	78
SoCalGas:
Accounts receivable – trade, net	$	223	$	83
Accounts receivable – other, net	19		15
Total allowances for credit losses	$	242	$	98

As we discuss below in “Note Receivable,” we have an interest-bearing promissory note due from KKR Pinnacle. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on this note receivable, including compounded interest and unamortized transaction costs, based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At June 30, 2023 and December 31, 2022, $6 million and $7 million, respectively, of expected credit losses are included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheets.

As we discuss in Note 5, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra Infrastructure from the SDSRA. On a quarterly basis, we evaluate credit losses and record liabilities for expected credit losses on this off-balance sheet arrangement based on external credit ratings, published default rate studies and the maturity date of the arrangement. At both June 30, 2023 and December 31, 2022, $6 million of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets.

INVENTORIES

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022
Natural gas	$	87	$	106	$	1	$	1	$	63	$	74
LNG	17		62		—		—		—		—
Materials and supplies	279		235		142		133		117		85
Total	$	383	$	403	$	143	$	134	$	180	$	159

NOTE RECEIVABLE

In November 2021, Sempra loaned $300 million to KKR Pinnacle in exchange for an interest-bearing promissory note that is due in full no later than October 2029 and bears compound interest at 5% per annum, which may be paid quarterly or added to the outstanding principal at the election of KKR Pinnacle. At June 30, 2023 and December 31, 2022, Other Long-Term Assets includes $324 million and $316 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, on Sempra’s Condensed Consolidated Balance Sheets.

CAPITALIZED FINANCING COSTS

Capitalized financing costs include capitalized interest costs and AFUDC related to both debt and equity financing of construction projects. We capitalize interest costs incurred to finance capital projects and interest at equity method investments that have not commenced planned principal operations.

The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest.


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra	$	110	$	60	$	183	$	117
SDG&E	31		26		62		54
SoCalGas	20		17		35		35

PROPERTY, PLANT AND EQUIPMENT

Sempra Infrastructure’s Sonora natural gas pipeline consists of two segments, the Sasabe-Puerto Libertad-Guaymas segment and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the pipeline in the Yaqui territory that has made that section inoperable since August 2017. Discussions with the CFE regarding the future of the pipeline are underway and the parties are working on restarting service on the pipeline, including the potential re-routing of a portion of the pipeline. If the parties do not agree on a definitive arrangement to re-route a portion of the pipeline or the parties do not agree on a new service start date, Sempra Infrastructure retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. At June 30, 2023, Sempra Infrastructure had $414 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline.

VARIABLE INTEREST ENTITIES

We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess:

▪the purpose and design of the VIE;

▪the nature of the VIE’s risks and the risks we absorb;

▪the power to direct activities that most significantly impact the economic performance of the VIE; and

▪the obligation to absorb losses or the right to receive benefits that could be significant to the VIE.

We will continue to evaluate our VIEs for any changes that may impact our determination of whether an entity is a VIE and if we are the primary beneficiary.

SDG&E

SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various PPAs that include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and indirectly Sempra, is the primary beneficiary.

SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements). SDG&E’s obligation to absorb natural gas costs may be a significant variable interest. In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based on our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which it considers the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If SDG&E determines that it is the primary beneficiary, SDG&E and Sempra consolidate the entity that owns the facility as a VIE.

In addition to tolling agreements, other variable interests involve various elements of fuel and power costs, and other components of cash flows expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities, including the operation and maintenance activities of the generating facility, that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects could be significant to the financial position and liquidity of SDG&E and Sempra.

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at June 30, 2023 and December 31, 2022. PPAs and tolling agreements that relate to SDG&E’s involvement with VIEs are primarily accounted for as finance leases. The carrying amounts of the assets and liabilities under these contracts are included in PP&E, net, and finance lease liabilities with balances of $1,181 million and $1,194 million at June 30, 2023 and December 31, 2022, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Sempra Texas Utilities

Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $13,869 million and $13,665 million at June 30, 2023 and December 31, 2022, respectively.

Sempra Infrastructure

Cameron LNG JV

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, including LNG production and operation and maintenance activities at the liquefaction facility. Therefore, we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment, including amounts recognized in AOCI related to interest-rate cash flow hedges at Cameron LNG JV, was $979 million at June 30, 2023 and $886 million at December 31, 2022. Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and our obligation under the SDSRA, which we discuss in Note 5.

CFIN

As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN, which is a VIE. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of CFIN, including modification, prepayment, and refinance decisions related to the financing arrangement with external lenders and Cameron LNG JV’s four project owners as well as the ability to determine and enforce remedies in the event of default. The conditional obligations of the Support Agreement represent a variable interest that we measure at fair value on a recurring basis (see Note 8). Sempra’s maximum exposure to loss under the terms of the Support Agreement is $979 million.

ECA LNG Phase 1

ECA LNG Phase 1 is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that ECA LNG Phase 1 will require future capital contributions or other financial support to finance the construction of the facility. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $1,330 million and $1,099 million of assets at June 30, 2023 and December 31, 2022, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $900 million and $685 million of liabilities at June 30, 2023 and December 31, 2022, respectively, consisting primarily of long-term debt, accounts payable and short-term debt attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 6, IEnova and TotalEnergies SE have provided guarantees for 83.4% and 16.6%, respectively, of the loan facility supporting construction of the liquefaction facility.

Port Arthur LNG

Port Arthur LNG is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that Port Arthur LNG will require future capital contributions or other financial support to finance the construction of the PA LNG Phase 1 project. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate Port Arthur LNG. Sempra consolidated $2,690 million of assets at June 30, 2023 consisting primarily of PP&E, net, attributable to Port Arthur LNG that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $455 million of liabilities at June 30, 2023 consisting primarily of accounts payable and long-term debt attributable to Port Arthur LNG for which creditors do not have recourse to the general credit of Sempra.

PENSION AND PBOP

Net Periodic Benefit Cost

The following tables provide the components of net periodic benefit cost. The components of net periodic benefit cost, other than the service cost component, are included in the Other Income (Expense), Net, table below.


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	29	$	42	$	3	$	6
Interest cost	39		29		10		7
Expected return on assets	(42)		(45)		(18)		(16)
Amortization of:
Prior service cost	1		2		—		—
Actuarial loss (gain)	2		5		(6)		(3)
Net periodic benefit cost (credit)	29		33		(11)		(6)
Regulatory adjustments	29		24		11		6
Total expense recognized	$	58	$	57	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	57	$	83	$	7	$	13
Interest cost	79		59		19		14
Expected return on assets	(85)		(91)		(35)		(32)
Amortization of:
Prior service cost (credit)	2		5		(1)		(1)
Actuarial loss (gain)	4		11		(12)		(7)
Net periodic benefit cost (credit)	57		67		(22)		(13)
Regulatory adjustments	58		(3)		22		13
Total expense recognized	$	115	$	64	$	—	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	8	$	10	$	—	$	1
Interest cost	10		6		2		2
Expected return on assets	(10)		(11)		(2)		(3)
Amortization of:
Actuarial loss	1		1		—		—
Net periodic benefit cost	9		6		—		—
Regulatory adjustments	4		7		—		—
Total expense recognized	$	13	$	13	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	16	$	20	$	1	$	3
Interest cost	20		13		4		3
Expected return on assets	(20)		(22)		(4)		(5)
Amortization of:
Actuarial loss (gain)	2		1		(1)		(1)
Net periodic benefit cost	18		12		—		—
Regulatory adjustments	8		2		—		—
Total expense recognized	$	26	$	14	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	17	$	28	$	2	$	5
Interest cost	26		21		7		6
Expected return on assets	(31)		(33)		(15)		(14)
Amortization of:
Prior service cost	1		2		—		—
Actuarial loss (gain)	—		4		(5)		(3)
Net periodic benefit cost (credit)	13		22		(11)		(6)
Regulatory adjustments	25		17		11		6
Total expense recognized	$	38	$	39	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	34	$	56	$	5	$	10
Interest cost	51		41		14		11
Expected return on assets	(60)		(64)		(30)		(27)
Amortization of:
Prior service cost (credit)	2		4		(1)		(1)
Actuarial loss (gain)	—		8		(10)		(6)
Net periodic benefit cost (credit)	27		45		(22)		(13)
Regulatory adjustments	50		(5)		22		13
Total expense recognized	$	77	$	40	$	—	$	—

DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS

In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $520 million and $505 million at June 30, 2023 and December 31, 2022, respectively.

SEMPRA EARNINGS PER COMMON SHARE

Basic EPS is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	315,007		314,845		314,963		315,595
Dilutive effect of stock options and RSUs(2)	1,053		1,022		1,129		1,052
Weighted-average common shares outstanding for diluted EPS	316,060		315,867		316,092		316,647

EPS:
Basic	$	1.91	$	1.78	$	4.99	$	3.71
Diluted	$	1.91	$	1.77	$	4.97	$	3.70

(1) Includes 355 and 399 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 358 and 403 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

(2) Due to market fluctuations of both Sempra common stock and the comparative indices used to determine the vesting percentage of our total shareholder return performance-based RSUs, which we discuss in Note 10 of the Notes to Consolidated Financial Statements in the Annual Report, dilutive RSUs may vary widely from period-to-period.

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and six months ended June 30, 2023 excludes 214,069 and 197,042 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and six months ended June 30, 2022 excludes 8,899 and 173,064 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Development Committee of Sempra’s board of directors granted 163,287 nonqualified stock options, 330,810 performance-based RSUs and 135,461 service-based RSUs in the six months ended June 30, 2023, primarily in January.

We discuss share-based compensation plans and related awards and the terms and conditions of Sempra’s equity securities further in Notes 10, 13 and 14 of the Notes to Consolidated Financial Statements in the Annual Report.

COMPREHENSIVE INCOME

The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, after amounts attributable to NCI.


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Three months ended June 30, 2023 and 2022
Sempra:
Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)
OCI before reclassifications	11		53		—		64
Amounts reclassified from AOCI	—		(4)		1		(3)
Net OCI	11		49		1		61
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)

Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
OCI before reclassifications	1		37		1		39
Amounts reclassified from AOCI(2)	10		11		2		23
Net OCI(2)	11		48		3		62
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
SDG&E:
Balance at March 31, 2023 and June 30, 2023					$	(7)	$	(7)





Balance at March 31, 2022 and June 30, 2022					$	(10)	$	(10)

SoCalGas:
Balance at March 31, 2023			$	(12)	$	(11)	$	(23)

Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

Balance at March 31, 2022			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)

(1) All amounts are net of income tax, if subject to tax, and after NCI.

(2) Total AOCI includes $9 of foreign currency translation adjustments associated with sale of NCI to ADIA, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Six months ended June 30, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	21		13		(13)		21
Amounts reclassified from AOCI	—		(9)		2		(7)
Net OCI	21		4		(11)		14
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		111		7		122
Amounts reclassified from AOCI(2)	10		15		4		29
Net OCI(2)	14		126		11		151
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
SDG&E:
Balance at December 31, 2022 and June 30, 2023					$	(7)	$	(7)





Balance at December 31, 2021 and June 30, 2022					$	(10)	$	(10)




SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)

Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)

(1) All amounts are net of income tax, if subject to tax, and after NCI.


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2023		2022
Sempra:
Foreign currency translation adjustments	$	—	$	1	Operation and Maintenance

Financial instruments:

Interest rate instruments	$	(14)	$	13	Equity Earnings(1)
Foreign exchange instruments	—		(1)		Revenues: Energy-Related Businesses
	1		1		Other Income (Expense), Net
Foreign exchange instruments	1		—		Equity Earnings
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense

Total, before income tax	(13)		12
	—		(4)		Income Tax Expense
Total, net of income tax	(13)		8
	9		3		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(4)	$	11

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	2	Other Income (Expense), Net
Amortization of prior service cost	—		1		Other Income (Expense), Net

Total, before income tax	1		3
	—		(1)		Income Tax Expense
Total, net of income tax	$	1	$	2

Total reclassifications for the period, net of income tax and after NCI	$	(3)	$	14





SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense









Total reclassifications for the period, net of income tax	$	1	$	1

(1) Equity earnings at our foreign equity method investees are recognized after tax.

(2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above).


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2023		2022
Sempra:
Foreign currency translation adjustments	$	—	$	1	Operation and Maintenance

Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	(21)		27		Equity Earnings(1)
Foreign exchange instruments	—		(2)		Revenues: Energy-Related Businesses
	2		1		Other Income (Expense), Net
Foreign exchange instruments	2		(1)		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense
	(6)		(6)		Other Income (Expense), Net
Total, before income tax	(24)		17
	3		(5)		Income Tax Expense
Total, net of income tax	(21)		12
	12		3		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(9)	$	15

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	4	Other Income (Expense), Net
Amortization of prior service cost	1		2		Other Income (Expense), Net
Total, before income tax	2		6
	—		(2)		Income Tax Expense
Total, net of income tax	$	2	$	4

Total reclassifications for the period, net of income tax and after NCI	$	(7)	$	20





SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense

Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income (Expense), Net
Amortization of prior service cost	1		—		Other Income (Expense), Net


Total, net of income tax	$	1	$	1

Total reclassifications for the period, net of income tax	$	2	$	2

(1) Equity earnings at our foreign equity method investees are recognized after tax.

(2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above).

For the three months and six months ended June 30, 2023 and 2022, reclassifications out of AOCI to net income were negligible for SDG&E.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Common Stock

On May 12, 2023, Sempra’s shareholders approved an amendment to Sempra’s Articles of Incorporation to increase the number of authorized shares of Sempra’s common stock from 750,000,000 to 1,125,000,000.

Sempra Common Stock Repurchases

In the six months ended June 30, 2023 and 2022, we repurchased 197,770 shares for $31 million and 196,592 shares for $26 million, respectively, of our common stock from long-term incentive plan participants to satisfy minimum statutory tax withholding requirements in connection with the vesting of RSUs and exercise of stock options.

On January 11, 2022, we entered into an ASR program under which we prepaid $200 million to repurchase shares of our common stock in a share forward transaction. A total of 1,472,756 shares were purchased under this program at an average price of $135.80 per share. The total number of shares purchased was determined by dividing the $200 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of January 12, 2022 through February 11, 2022, minus a fixed discount. The ASR program was completed on February 11, 2022.

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 1,471,957 shares were purchased under this program at an average price of $169.84 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.

Other Noncontrolling Interests

The following table provides information about NCI held by others in subsidiaries or entities consolidated by us and recorded in Other Noncontrolling Interests in Total Equity on Sempra’s Condensed Consolidated Balance Sheets.


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	2,424	$	2,060
SI Partners subsidiaries(1)	0.1 - 30.0		0.1 - 16.6		734		61
Total Sempra					$	3,158	$	2,121

(1) SI Partners has subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

Sempra Infrastructure

Sale of NCI to KKR Denali. In March 2023, an indirect subsidiary of SI Partners entered into an agreement for the sale to KKR Denali of an indirect interest in the PA LNG Phase 1 project. KKR Denali intends to acquire a 42% indirect interest in the PA LNG Phase 1 project for approximately $108 million, plus its pro rata equity share of development costs incurred prior to the closing that exceed $439 million, subject to customary post-closing adjustments. We are targeting the closing of the sale of NCI to KKR Denali in the third quarter of 2023, subject to regulatory approvals and other closing conditions. If the closing conditions are satisfied and KKR Denali fails to complete the closing, then KKR Denali must pay a termination fee of $130 million.

In connection with the closing of the sale of NCI to KKR Denali, the associated limited liability company agreement will be amended and restated to include KKR Denali as a member of such company and to set forth certain governance and other agreements with respect to the funding of the PA LNG Phase 1 project. Pursuant to the limited liability company agreement, (i) the indirect subsidiary of SI Partners (a) will be the managing member; (b) will exclusively hold the right to make decisions with respect to certain expansions, such as the potential PA LNG Phase 2 project; (c) will have certain rights to preferential distributions from specified revenues and expansion true-up payments; and, (d) through a parent entity that is a subsidiary of Sempra, will bear a disproportionately higher allocation of certain capital contribution commitments in certain budgetary overrun scenarios, and (ii) KKR Denali will receive certain investor protection voting rights. The indirect subsidiary of SI Partners and KKR Denali will also make 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 those certain budget overrun scenarios discussed above.

Upon closing of the sale of NCI to KKR Denali, Sempra would hold an indirect interest in the PA LNG Phase 1 project of 19.6%.

Sale of NCI to ConocoPhillips Affiliate. In March 2023, an indirect subsidiary of SI Partners completed the sale of an indirect 30% NCI in the PA LNG Phase 1 project to an affiliate of ConocoPhillips for aggregate cash consideration of approximately $265 million, subject to customary post-closing adjustments. As a result of this sale, we recorded a $237 million increase in equity held

by NCI and an increase in Sempra’s shareholders’ equity of $18 million, net of $3 million in transaction costs and $7 million in tax impacts.

At the closing of the sale of NCI to the ConocoPhillips affiliate, the associated limited liability company agreement was amended and restated to include the ConocoPhillips affiliate as a member of such company and to set forth certain governance and other agreements with respect to the funding of the PA LNG Phase 1 project. Pursuant to the limited liability company agreement, such company will generally be managed by a board of managers, initially constituting three representatives appointed by the indirect subsidiary of SI Partners and two representatives appointed by the ConocoPhillips affiliate.

The indirect subsidiary of SI Partners and the ConocoPhillips affiliate have made certain customary capital contribution commitments to fund their respective pro rata equity share of the total anticipated capital calls for the equity portion of the anticipated development costs of the PA LNG Phase 1 project. In addition, both SI Partners and ConocoPhillips 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.

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. Following the closing of the transaction, Sempra, KKR Pinnacle and ADIA directly or indirectly own 70%, 20%, and 10%, respectively, of the outstanding Class A Units of SI Partners, which excludes the non-voting Sole Risk Interests held only by Sempra. 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 in tax impacts. Transaction costs include $10 million paid to ADIA for reimbursement of certain expenses that ADIA incurred in connection with closing the transaction.

Contributions from NCI. In October 2021, KKR Pinnacle acquired a 20% NCI in SI Partners. Under the limited partnership agreement that governs our and KKR Pinnacle’s respective rights and obligations in respect of our and their ownership interests in SI Partners, KKR Pinnacle is entitled to a $200 million credit from Sempra to be applied to capital calls once an LNG project reaches a positive final investment decision and meets certain projected internal rates of return. In the three months and six months ended June 30, 2023, KKR Pinnacle used $186 million of this credit to fund its share of contributions to SI Partners. As a result, we recorded a $186 million increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $134 million, net of deferred income taxes. We expect that KKR Pinnacle will fully utilize the remaining balance of this credit in the third quarter of 2023.

TRANSACTIONS WITH AFFILIATES

We summarize amounts due from and to unconsolidated affiliates at Sempra, SDG&E and SoCalGas in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	15	$	41
Various affiliates	11		13
Total due from unconsolidated affiliates – current	$	26	$	54

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V. – 5.5% Note due January 9, 2024	$	(5)	$	—
Total due to unconsolidated affiliates – current	$	(5)	$	—

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	—	$	(40)
5.5% Note due January 14, 2025	(23)		(23)
5.5% Note due July 16, 2025	(22)		(21)
5.5% Note due January 14, 2026	(19)		(19)
5.5% Note due July 14, 2026	(11)		(11)
5.5% Note due January 19, 2027	(14)		—
TAG – 5.74% Note due December 17, 2029	(193)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(282)	$	(301)
SDG&E:
Various affiliates	$	1	$	—
Total due from unconsolidated affiliates – current	$	1	$	—

Sempra	$	(29)	$	(49)
SoCalGas	—		(72)
Various affiliates	(14)		(14)
Total due to unconsolidated affiliates – current	$	(43)	$	(135)

Income taxes due (to) from Sempra(2)	$	(32)	$	10
SoCalGas:
SDG&E	$	—	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	1	$	77

Sempra	$	(36)	$	(36)
Total due to unconsolidated affiliates – current	$	(36)	$	(36)

Income taxes due to Sempra(2)	$	(11)	$	(16)

(1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding.

(2) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra, and their respective income tax expense is computed as an amount equal to that which would result from each company having always filed a separate return. Amounts include current and noncurrent income taxes due to/from Sempra.

The following table summarizes income statement information from unconsolidated affiliates.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra:
Revenues	$	11	$	15	$	24	$	22

Interest income	—		4		—		14
Interest expense	4		4		8		8
SDG&E:
Revenues	$	6	$	4	$	10	$	8
Cost of sales	27		26		57		50
SoCalGas:
Revenues	$	28	$	23	$	62	$	49
Cost of sales(1)	4		(4)		35		(4)

(1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.

Guarantees

Sempra provided guarantees related to Cameron LNG JV’s SDSRA and CFIN’s Support Agreement, which remain outstanding. We discuss these guarantees in Note 5 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

OTHER INCOME (EXPENSE), NET

Other Income (Expense), Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra:
Allowance for equity funds used during construction	$	37	$	34	$	70	$	69
Investment gains (losses), net(1)	5		(34)		17		(47)
(Losses) gains on interest rate and foreign exchange instruments, net	(1)		(1)		4		5
Foreign currency transaction gains (losses), net(2)	3		(3)		4		(22)
Non-service components of net periodic benefit cost	(26)		(9)		(51)		32
Interest on regulatory balancing accounts, net	19		4		37		5
Sundry, net	(6)		8		(9)		(5)
Total	$	31	$	(1)	$	72	$	37
SDG&E:
Allowance for equity funds used during construction	$	23	$	21	$	46	$	42
Non-service components of net periodic benefit cost	(5)		(2)		(9)		9
Interest on regulatory balancing accounts, net	11		3		21		4
Sundry, net	(7)		—		(8)		1
Total	$	22	$	22	$	50	$	56
SoCalGas:
Allowance for equity funds used during construction	$	14	$	13	$	24	$	26
Non-service components of net periodic benefit cost	(19)		(6)		(38)		26
Interest on regulatory balancing accounts, net	8		1		16		1
Sundry, net	(2)		(4)		(9)		(15)
Total	$	1	$	4	$	(7)	$	38

(1) Represents net investment gains (losses) on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are offset by corresponding changes in compensation expense related to the plans, recorded in O&M on the Condensed Consolidated Statements of Operations.

(2) Includes losses of $11 in the six months ended June 30, 2022 from translation to U.S. dollars of a Mexican peso-denominated loan to IMG, which are offset by corresponding amounts included in Equity Earnings on the Condensed Consolidated Statement of Operations.

INCOME TAXES

We provide our calculations of ETRs in the following table.


INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2023			2022			2023			2022
Sempra:
Income tax expense	$	175		$	80		$	551		$	414

Income before income taxes and equity earnings	$	523		$	364		$	1,852		$	1,029
Equity earnings, before income tax(1)	153			159			285			302
Pretax income	$	676		$	523		$	2,137		$	1,331

Effective income tax rate	26		%	15		%	26		%	31		%
SDG&E:
Income tax expense	$	4		$	42		$	11		$	106
Income before income taxes	$	188		$	218		$	453		$	516
Effective income tax rate	2		%	19		%	2		%	21		%
SoCalGas:
Income tax (benefit) expense	$	(21)		$	19		$	73		$	103
Income before income taxes	$	135		$	107		$	589		$	525
Effective income tax rate	(16)		%	18		%	12		%	20		%

(1) We discuss how we recognize equity earnings in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

Sempra, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted ETR anticipated for the full year. Unusual and infrequent items and items that cannot be reliably estimated are recorded in the interim period in which they occur, which can result in variability in the ETR.

For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment:

▪repairs expenditures related to a certain portion of utility plant fixed assets

▪the equity portion of AFUDC, which is non-taxable

▪a portion of the cost of removal of utility plant assets

▪utility self-developed software expenditures

▪depreciation on a certain portion of utility plant assets

▪state income taxes

AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment.

Under the IRA, beginning in 2023, the scope of projects eligible for investment tax credits was expanded to include standalone energy storage projects. The IRA also provided an election that prospectively permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset. Under this election, SDG&E recorded a regulatory liability to offset these investment tax credits, which reduced SDG&E’s and Sempra’s ETR in 2023.

On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the three months and six months ended June 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. SoCalGas recorded an associated

regulatory liability for the portion that will benefit customers in the future. We are assessing the potential future impacts of this Revenue Procedure.In the six months ended June 30, 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.

CONDENSED BALANCE SHEETS - SDG&E - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

$ 1,077

$ 370

^[1]

1,970

2,635

^[1]

489

685

^[1]

^[1]

383

403

^[1]

Prepaid expenses

159

268

^[1]

Fixed-price contracts and other derivatives

105

351

^[1]

256

803

^[1]

143

141

^[1]

^[1]

4,847

5,912

^[1]

3,227

2,588

^[1]

Nuclear decommissioning trusts

1,045

796

^[1]

863

841

^[1]

722

655

^[1]

Wildfire fund

288

303

^[1]

1,549

1,382

^[1]

26,402

24,880

^[1]

68,270

63,893

^[1]

(16,792)

(16,111)

^[1]

51,478

47,782

^[1]

82,727

78,574

^[1]

2,512

3,352

^[1]

364

484

^[1]

Current portion of long-term debt and finance leases

650

504

^[1]

924

1,019

^[1]

143

141

^[1]

8,451

9,899

^[1]

27,521

24,548

^[1]

3,435

3,341

^[1]

Pension and other postretirement benefit plan obligations, net of plan assets

800

565

^[1]

346

410

^[1]

5,064

4,591

^[1]

3,536

3,546

^[1]

2,278

2,117

^[1]

15,741

14,871

^[1]

^[1]

Equity:

12,044

12,160

^[1]

15,024

14,201

^[1]

(121)

(135)

^[1]

27,836

27,115

^[1]

82,727

78,574

^[1]

Related Party

^[1]

Nonrelated Party

1,052

1,380

^[1]

332

^[1]

813

799

^[1]

149

110

^[1]

^[1]

143

134

^[1]

Prepaid expenses

179

^[1]

Fixed-price contracts and other derivatives

247

^[1]

113

^[1]

^[1]

^[1]

1,678

1,630

^[1]

1,564

1,219

^[1]

Nuclear decommissioning trusts

230

196

^[1]

863

841

^[1]

364

281

^[1]

Wildfire fund

288

303

^[1]

136

146

^[1]

3,445

2,986

^[1]

29,704

28,574

^[1]

(7,041)

(6,768)

^[1]

22,663

21,806

^[1]

27,786

26,422

^[1]

205

^[1]

Accounts payable

757

744

^[1]

Interest payable

^[1]

140

^[1]

Accrued franchise fees

120

^[1]

Current portion of long-term debt and finance leases

232

110

^[1]

891

489

^[1]

^[1]

107

^[1]

2,572

2,319

^[1]

8,865

8,497

^[1]

2,406

2,298

^[1]

Pension and other postretirement benefit plan obligations, net of plan assets

119

^[1]

^[1]

2,576

2,540

^[1]

779

789

^[1]

927

789

^[1]

6,840

6,539

^[1]

^[1]

Equity:

Preferred stock

^[1]

1,660

^[1]

7,856

7,414

^[1]

(7)

^[1]

9,509

9,067

^[1]

San Diego Gas and Electric Company | Related Party

27,786

26,422

^[1]

San Diego Gas and Electric Company | Nonrelated Party

135

^[1]

$ 271

$ 193

^[1]

[1]	Derived from audited financial statements.

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

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

Amount of the cost of borrowed funds accounted for as interest expense.

Earnings Per Share Computations Table

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

SUBSEQUENT EVENT (Tables)

6 Months Ended

Jun. 30, 2023

Subsequent Events [Abstract]


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	315,007		314,845		314,963		315,595
Dilutive effect of stock options and RSUs(2)	1,053		1,022		1,129		1,052
Weighted-average common shares outstanding for diluted EPS	316,060		315,867		316,092		316,647

EPS:
Basic	$	1.91	$	1.78	$	4.99	$	3.71
Diluted	$	1.91	$	1.77	$	4.97	$	3.70

The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented:


PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	630,014		629,691		629,926		631,190
Dilutive effect of stock options and RSUs	2,107		2,044		2,259		2,104
Weighted-average common shares outstanding for diluted EPS	632,121		631,735		632,185		633,294

EPS:
Basic	$	0.96	$	0.89	$	2.50	$	1.86
Diluted	$	0.95	$	0.89	$	2.49	$	1.85

(1) Includes 710 and 798 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2023 and 2022, respectively, and 716 and 806 of such RSUs for the six months ended June 30, 2023 and 2022, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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

FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2023 and December 31, 2022. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair-valued assets and liabilities and their placement within the fair value hierarchy. We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2022.

The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.”

The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests).

Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following:

▪Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2).

▪For commodity contracts, interest rate instruments and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below in “Level 3 Information – SDG&E.”

▪Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1).

▪As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra Infrastructure.”


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	22	$	2	$	—	$	24
Equity securities	318		4		—		322
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	25		14		—		39
Municipal bonds	—		266		—		266
Other securities	—		218		—		218
Total debt securities	25		498		—		523
Total nuclear decommissioning trusts(1)	365		504		—		869
Short-term investments held in Rabbi Trust	51		—		—		51
Interest rate instruments	—		62		—		62
Commodity contracts not subject to rate recovery	—		19		—		19
Effect of netting and allocation of collateral(2)	143		—		—		143
Commodity contracts subject to rate recovery	—		1		20		21
Effect of netting and allocation of collateral(2)	65		—		5		70
Support Agreement, net of related guarantee fees	—		—		23		23
Total	$	624	$	586	$	48	$	1,258
Liabilities:
Interest rate instruments	$	—	$	2	$	—	$	2
Foreign exchange instruments	—		15		—		15
Commodity contracts not subject to rate recovery	—		11		—		11
Commodity contracts subject to rate recovery	14		51		—		65
Effect of netting and allocation of collateral(2)	(14)		—		—		(14)
Total	$	—	$	79	$	—	$	79

(1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SEMPRA (CONTINUED)
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at December 31, 2022
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	10	$	1	$	—	$	11
Equity securities	293		4		—		297
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		13		—		40
Municipal bonds	—		270		—		270
Other securities	—		227		—		227
Total debt securities	27		510		—		537
Total nuclear decommissioning trusts(1)	330		515		—		845
Short-term investments held in Rabbi Trust	55		—		—		55
Interest rate instruments	—		76		—		76
Commodity contracts not subject to rate recovery	—		273		—		273
Effect of netting and allocation of collateral(2)	451		—		—		451
Commodity contracts subject to rate recovery	82		19		35		136
Effect of netting and allocation of collateral(2)	12		—		6		18
Support Agreement, net of related guarantee fees	—		—		17		17
Total	$	930	$	883	$	58	$	1,871
Liabilities:
Foreign exchange instruments	$	—	$	8	$	—	$	8
Interest rate and foreign exchange instruments	—		105		—		105
Commodity contracts not subject to rate recovery	—		191		—		191
Commodity contracts subject to rate recovery	—		70		—		70
Total	$	—	$	374	$	—	$	374

1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	22	$	2	$	—	$	24
Equity securities	318		4		—		322
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	25		14		—		39
Municipal bonds	—		266		—		266
Other securities	—		218		—		218
Total debt securities	25		498		—		523
Total nuclear decommissioning trusts(1)	365		504		—		869
Commodity contracts subject to rate recovery	—		—		20		20
Effect of netting and allocation of collateral(2)	64		—		5		69
Total	$	429	$	504	$	25	$	958
Liabilities:
Commodity contracts subject to rate recovery	$	14	$	5	$	—	$	19
Effect of netting and allocation of collateral(2)	(14)		—		—		(14)
Total	$	—	$	5	$	—	$	5

	Fair value at December 31, 2022
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	10	$	1	$	—	$	11
Equity securities	293		4		—		297
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		13		—		40
Municipal bonds	—		270		—		270
Other securities	—		227		—		227
Total debt securities	27		510		—		537
Total nuclear decommissioning trusts(1)	330		515		—		845
Commodity contracts subject to rate recovery	82		3		35		120
Effect of netting and allocation of collateral(2)	11		—		6		17
Total	$	423	$	518	$	41	$	982
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Total	$	—	$	1	$	—	$	1

(1) Excludes receivables (payables), net.

(2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.


RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at June 30, 2023
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	1	$	—	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	46	$	—	$	46
Total	$	—	$	46	$	—	$	46

	Fair value at December 31, 2022
Assets:
Commodity contracts subject to rate recovery	$	—	$	16	$	—	$	16
Effect of netting and allocation of collateral(1)	1		—		—		1
Total	$	1	$	16	$	—	$	17
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	69	$	—	$	69
Total	$	—	$	69	$	—	$	69

(1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

Level 3 Information

SDG&E


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended June 30,
	2023		2022
Balance at April 1	$	30	$	58
Realized and unrealized losses	(4)		(30)
Allocated transmission instruments	(2)		(6)
Settlements	(4)		11
Balance at June 30	$	20	$	33
Change in unrealized losses relating to instruments still held at June 30	$	(7)	$	(23)

	Six months ended June 30,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized losses	(8)		(23)
Allocated transmission instruments	(2)		(6)
Settlements	(5)		8
Balance at June 30	$	20	$	33
Change in unrealized losses relating to instruments still held at June 30	$	(9)	$	(18)

(1) Excludes the effect of the contractual ability to settle contracts under master netting agreements.

Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness.

CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following year. For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below:


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

Settlement year	Price per MWh					Median price per MWh
2023	$	(3.09)	to	$	10.71	$	(0.56)
2022	(3.67)		to	6.96		(0.70)

The impact associated with discounting is not significant. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a significantly higher (lower) fair value measurement. We summarize CRR volumes in Note 7.

Long-term, fixed-price electricity positions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. The range and weighted-average price of these inputs at June 30 were as follows:


LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS

Settlement year						Weighted-average price per MWh
2023	$	22.75	to	$	117.50	$	74.02
2022	25.25		to	125.00		66.36

A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 7.

Realized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings.

Sempra Infrastructure

The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra.


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2023		2022
Balance at April 1	$	24	$	12
Realized and unrealized gains(1)	1		6
Settlements	(2)		(2)
Balance at June 30(2)	$	23	$	16
Change in unrealized gains relating to instruments still held at June 30	$	1	$	5

	Six months ended June 30,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	10		14
Settlements	(4)		(5)
Balance at June 30(2)	$	23	$	16
Change in unrealized gains relating to instruments still held at June 30	$	9	$	13

(1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Condensed Consolidated Statements of Operations.

(2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet.

The fair value of the Support Agreement, net of related guarantee fees, is based on a discounted cash flow model using a probability of default and survival methodology. Our estimate of fair value considers inputs such as third-party default rates, credit ratings, recovery rates, and risk-adjusted discount rates, which may be readily observable, market corroborated or generally unobservable inputs. Because CFIN’s credit rating and related default and survival rates are unobservable inputs that are significant to the valuation, the Support Agreement, net of related guarantee fees, is classified as Level 3. We assigned CFIN an internally developed credit rating of A3 and relied on default rate data published by Moody’s to assign a probability of default. A hypothetical change in the credit rating up or down one notch could result in a significant change in the fair value of the Support Agreement.

Fair Value of Financial Instruments

The fair values of certain of our financial instruments (cash, accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Condensed Consolidated Balance Sheets.


FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2023
Sempra:

Long-term note receivable(1)	$	326	$	—	$	—	$	296	$	296
Long-term amounts due to unconsolidated affiliates	287		—		251		—		251
Total long-term debt(2)	27,419		—		24,630		—		24,630
SDG&E:
Total long-term debt(3)	$	8,600	$	—	$	7,535	$	—	$	7,535
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	6,270	$	—	$	6,270

	December 31, 2022
Sempra:
Long-term note receivable(1)	$	318	$	—	$	—	$	286	$	286
Long-term amounts due to unconsolidated affiliates	301		—		263		—		263
Total long-term debt(2)	24,513		—		21,549		—		21,549
SDG&E:
Total long-term debt(3)	$	7,800	$	—	$	6,726	$	—	$	6,726
SoCalGas:
Total long-term debt(4)	$	6,059	$	—	$	5,538	$	—	$	5,538

We provide the fair values for the securities held in the NDT related to SONGS in Note 9.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS NARRATIVE (Details) - USD ($) $ / shares in Units, $ in Millions					1 Months Ended		3 Months Ended		6 Months Ended
	Mar. 20, 2023	Jun. 01, 2022	Apr. 06, 2022	Jan. 11, 2022	Mar. 31, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Aug. 02, 2023	May 12, 2023	May 11, 2023	Dec. 31, 2022	Dec. 21, 2021	Oct. 01, 2021
Noncontrolling Interest [Line Items]
Common stock, shares authorized (in shares)							1,125,000,000		1,125,000,000			1,125,000,000	750,000,000	1,125,000,000
Increase in equity							$ 498.0	$ 7.0	$ 595.0	$ 13.0
Increase in shareholders' equity								$ 1,418.0	255.0	$ 1,418.0
Port Arthur LNG
Noncontrolling Interest [Line Items]
Increase in equity	$ 237.0
SI Partners
Noncontrolling Interest [Line Items]
Increase in shareholders' equity									186.0
Sale of noncontrolling interest, change in equity									134.0
Sempra Infrastructure \| SI Partners
Noncontrolling Interest [Line Items]
Increase in shareholders' equity		$ 709.0
Sale of noncontrolling interest, change in equity		710.0
Sale of noncontrolling interest, transaction costs		12.0
Reduction to deferred income tax liability		300.0
Sale of noncontrolling interest, transaction costs reimbursed		$ 10.0
KKR Denali \| SI Partners
Noncontrolling Interest [Line Items]
Cash consideration for minimum amount of interest transferred					$ 108.0
Share of development costs incurred, threshold					439.0
Termination fee					$ 130.0
Indirect Subsidiary Of SI Partners \| Port Arthur LNG
Noncontrolling Interest [Line Items]
Cash consideration	265.0
Increase in shareholders' equity	18.0
Sale of noncontrolling interest, transaction costs	3.0
Sale of noncontrolling interest, tax impacts	7.0
Funding commitment, aggregate amount	$ 9,000.0
KKR \| SI Partners
Noncontrolling Interest [Line Items]
Funding commitment, aggregate amount																$ 200.0
Funding used							$ 186.0		$ 186.0
Subsequent Event
Noncontrolling Interest [Line Items]
Common stock, shares authorized (in shares)											1,125,000,000
Port Arthur LNG \| Indirect Subsidiary Of SI Partners
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	30.00%
Funding commitment (in percent)	110.00%
Guaranteed funding amount (in percent)	70.00%
Port Arthur LNG \| Minimum \| KKR Denali
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)							19.60%		19.60%
SI Partners \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)							30.00%		30.00%					30.00%
SI Partners \| KKR Denali
Noncontrolling Interest [Line Items]
Ownership percentage, minimum indirect interest transferred (in percent)						42.00%
SI Partners \| Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest (as a percent)															10.00%
Sale of noncontrolling interest, aggregate purchase price															$ 1,700.0
SI Partners \| KKR
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)															20.00%	20.00%
SI Partners \| Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)															10.00%
SI Partners \| Sempra
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)															70.00%
SI Partners subsidiaries \| Minimum \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)							0.10%		0.10%					0.10%
SI Partners subsidiaries \| Maximum \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)							30.00%		30.00%					16.60%
Common stock
Noncontrolling Interest [Line Items]
Share repurchase program, number of shares repurchased (in shares)			1,471,957	1,472,756					197,770	196,592
Common stock repurchased									$ 31.0	$ 26.0
Accelerated share repurchase program, prepaid amount			$ 250.0	$ 200.0
Common stock repurchased, average price (in dollars per share)			$ 169.84	$ 135.80

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

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

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

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

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022	Nov. 30, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Loan to KKR in exchange for interest-bearing promissory note			$ 300
Compound interest rate (as a percent)	5.00%
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable, net	$ 324	$ 316

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

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

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

Nominal or face amount used to calculate payments on the derivative liability.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($)
$ in Millions

6 Months Ended

Jun. 30, 2023

Dec. 31, 2022

Property plant and equipment, net

$ 51,478

$ 47,782

^[1]

Finance lease obligations

1,351

1,343

Equity method investment

13,869

13,665

^[1]

Oncor Holdings | Sempra Texas Utilities

82,727

78,574

^[1]

Cameron LNG Holdings | Sempra Infrastructure

Equity method investment

13,869

13,665

Equity method investment

979

886

Property plant and equipment, net

22,663

21,806

^[1]

Finance lease obligations

1,241

1,256

$ 27,786

26,422

^[1]

IEnova | ECA LNG JV

Ownership percentage in consolidated entity (in percentage)

83.40%

Subsidiary of TOTAL SE | ECA LNG JV

Ownership percentage in consolidated entity (in percentage)

16.60%

Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure

Maximum exposure under guarantor obligations

$ 979

Variable Interest Entity, Not Primary Beneficiary | San Diego Gas and Electric Company

Property plant and equipment, net

1,181

1,194

Finance lease obligations

1,181

1,194

Variable Interest Entity, Primary Beneficiary | ECA LNG JV | Sempra Infrastructure

Variable Interest Entity, Primary Beneficiary | Port Arthur LNG | Sempra Infrastructure

1,330

1,099

Liabilities

900

$ 685

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

2,690

Liabilities

$ 455

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

^[1]

$ 27,115

$ 64

$ 39

$ 122

(3)

(7)

151

Total accumulated other comprehensive income (loss)

27,836

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(182)

(229)

(135)

(318)

Foreign currency translation adjustments

(121)

(167)

(121)

(167)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(49)

(76)

(59)

(79)

AOCI associated with noncontrolling interests

(38)

(65)

(38)

(65)

Financial instruments

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(35)

(78)

(156)

111

(4)

(9)

126

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(30)

Pension and PBOP

(98)

(75)

(86)

(83)

(13)

(11)

(97)

(72)

(97)

(72)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

^[1]

9,067

San Diego Gas and Electric Company | Total accumulated other comprehensive income (loss)

9,509

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(7)

(10)

(7)

(10)

San Diego Gas and Electric Company | Pension and PBOP

(7)

(10)

(7)

(10)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(7)

(10)

(7)

(10)

(7)

(10)

(7)

(10)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

^[1]

6,698

Southern California Gas Company | Total accumulated other comprehensive income (loss)

7,215

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(23)

(30)

(24)

(31)

Southern California Gas Company | Financial instruments

(22)

(29)

(22)

(29)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(12)

(13)

(12)

(13)

Southern California Gas Company | Pension and PBOP

(11)

(12)

(11)

(12)

AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]

(11)

(17)

(12)

(18)

Schedule of Line of Credit Facilities

$ (11)

$ (17)

$ (11)

$ (17)

[1]	Derived from audited financial statements.

DEBT AND CREDIT FACILITIES (Tables)

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]


COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Letters of credit outstanding		Available unused credit
Sempra	October 2027	$	4,000	$	(813)	$	—	$	—	$	3,187
SDG&E	October 2027	1,500		—		—		—		1,500
SoCalGas	October 2027	1,200		(238)		—		—		962
SI Partners	November 2024	1,000		—		—		—		1,000
IEnova and SI Partners	September 2023	350		—		(350)		—		—
IEnova and SI Partners	December 2023	150		—		—		—		150
IEnova and SI Partners	February 2024	1,500		—		(1,086)		—		414
Port Arthur LNG	March 2030	200		—		—		(15)		185
Total		$	9,900	$	(1,051)	$	(1,436)	$	(15)	$	7,398


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		June 30, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2024 - May 2024	$	15
SoCalGas	November 2023 - October 2024	20
Sempra Infrastructure	July 2023 - October 2043	311
Parent and other	September 2023 - June 2024	168
Total		$	514

The weighted-average interest rates on all short-term debt were as follows:


WEIGHTED-AVERAGE INTEREST RATES

	June 30, 2023		December 31, 2022
Sempra	5.92	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.14		4.71

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

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

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

The entire disclosure for change in accounting principle. Includes, but is not limited to, nature, reason, and method of adopting amendment to accounting standards or other change in accounting principle.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Topic 310
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481925/310-20-65-2

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

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Jun. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
San Diego Gas and Electric Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	117,000,000	117,000,000

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

$ 1,077

$ 370

^[1]

Restricted cash

^[1]

1,970

2,635

^[1]

489

685

^[1]

^[1]

Income taxes receivable

113

^[1]

383

403

^[1]

Prepaid expenses

159

268

^[1]

Fixed-price contracts and other derivatives

105

351

^[1]

256

803

^[1]

143

141

^[1]

^[1]

4,847

5,912

^[1]

Restricted cash

^[1]

3,227

2,588

^[1]

Nuclear decommissioning trusts

1,045

796

^[1]

863

841

^[1]

Dedicated assets in support of certain benefit plans

520

505

^[1]

149

135

^[1]

Investment in Oncor Holdings

722

655

^[1]

13,869

13,665

^[1]

Other investments

2,146

2,012

^[1]

Goodwill

1,602

^[1]

Other intangible assets

331

344

^[1]

Wildfire fund

288

303

^[1]

1,549

1,382

^[1]

26,402

24,880

^[1]

68,270

63,893

^[1]

(16,792)

(16,111)

^[1]

51,478

47,782

^[1]

82,727

78,574

^[1]

Dividends and interest payable

2,512

3,352

^[1]

Accounts payable – trade

1,790

1,994

^[1]

Accounts payable – other

234

275

^[1]

651

621

^[1]

364

484

^[1]

Current portion of long-term debt and finance leases

650

504

^[1]

924

1,019

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

143

141

^[1]

8,451

9,899

^[1]

27,521

24,548

^[1]

Due to unconsolidated affiliates

282

301

^[1]

3,435

3,341

^[1]

Pension and other postretirement benefit plan obligations, net of plan assets

800

565

^[1]

346

410

^[1]

5,064

4,591

^[1]

3,536

3,546

^[1]

2,278

2,117

^[1]

15,741

14,871

^[1]

^[1]

Equity:

12,044

12,160

^[1]

15,024

14,201

^[1]

(121)

(135)

^[1]

Preferred stock of subsidiary

27,836

27,115

^[1]

^[1]

3,158

2,121

^[1]

Total equity

31,014

29,256

^[1]

82,727

78,574

^[1]

Related Party

^[1]

Nonrelated Party

Derivative Instruments and Hedging Activities Disclosure [Abstract]

1,052

1,380

^[1]

Series C Preferred Stock

Equity:

Preferred stock

$ 889

^[1]

[1]	Derived from audited financial statements.

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2023

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

June 30, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

380

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

271

224

Notional Amounts of Derivatives Table

The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments and the contingent interest rate swap.

INTEREST RATE DERIVATIVES

(Dollars in millions)

June 30, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,454

2023-2048

294

2023-2034

(1) At June 30, 2023 and December 31, 2022, cash flow hedges accrued interest based on a notional of $491 and $294, respectively.

The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments.


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	June 30, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	65		2023-2024	111		2023-2024

Derivative Instruments on the Condensed Consolidated Balance Sheets Table


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	16	$	46	$	—	$	(2)
Foreign exchange instruments	—		—		(15)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	251		35		(236)		(42)
Associated offsetting commodity contracts	(232)		(35)		232		35
Commodity contracts subject to rate recovery	20		17		(64)		(17)
Associated offsetting commodity contracts	(12)		(4)		12		4
Associated offsetting cash collateral	—		—		10		4
Net amounts presented on the balance sheet	43		59		(61)		(18)
Additional cash collateral for commodity contracts not subject to rate recovery	143		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	70		—		—		—
Total(2)	$	256	$	59	$	(61)	$	(18)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	18	$	17	$	(26)	$	(8)
Associated offsetting commodity contracts	(11)		(4)		11		4
Associated offsetting cash collateral	—		—		10		4
Net amounts presented on the balance sheet	7		13		(5)		—
Additional cash collateral for commodity contracts subject to rate recovery	69		—		—		—
Total(2)	$	76	$	13	$	(5)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	2	$	—	$	(38)	$	(9)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	1		—		(37)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	2	$	—	$	(37)	$	(9)

(1) Included in Other Current Assets for SoCalGas.

(2) Normal purchase contracts previously measured at fair value are excluded.


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2022
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	10	$	33	$	—	$	—
Foreign exchange instruments	—		—		(7)		(1)
Interest rate and foreign exchange instruments	—		—		(105)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	480		133		(399)		(132)
Associated offsetting commodity contracts	(301)		(39)		301		39
Commodity contracts subject to rate recovery	138		27		(97)		(2)
Associated offsetting commodity contracts	(27)		(2)		27		2
Interest rate instrument	33		—		—		—
Net amounts presented on the balance sheet	333		152		(280)		(94)
Additional cash collateral for commodity contracts not subject to rate recovery	451		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total(2)	$	802	$	152	$	(280)	$	(94)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	107	$	27	$	(13)	$	(2)
Associated offsetting commodity contracts	(12)		(2)		12		2
Net amounts presented on the balance sheet	95		25		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	17		—		—		—
Total(2)	$	112	$	25	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	31	$	—	$	(84)	$	—
Associated offsetting commodity contracts	(15)		—		15		—
Net amounts presented on the balance sheet	16		—		(69)		—
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	17	$	—	$	(69)	$	—

(1) Included in Other Current Assets for SoCalGas.

(2) Normal purchase contracts previously measured at fair value are excluded.

Cash Flow Hedge Impact on the Condensed Consolidated Statements of Comprehensive Income Table

The following table includes the effects of derivative instruments designated as cash flow hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI.


CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	94	$	13	Interest Expense	$	—	$	—
Interest rate instruments	41		50		Equity Earnings(1)	14		(13)
Foreign exchange instruments	(2)		—		Revenues: Energy- Related Businesses	—		1
					Other Income (Expense), Net	(1)		(1)
Foreign exchange instruments	(1)		—		Equity Earnings(1)	(1)		—
Interest rate and foreign exchange instruments	—		4		Interest Expense	1		1

Total	$	132	$	67		$	13	$	(12)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

	Six months ended June 30,					Six months ended June 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	17	$	35	Interest Expense	$	—	$	1
Interest rate instruments	24		144		Equity Earnings(1)	21		(27)
Foreign exchange instruments	(8)		(3)		Revenues: Energy- Related Businesses	—		2
					Other Income (Expense), Net	(2)		(1)
Foreign exchange instruments	(6)		(2)		Equity Earnings(1)	(2)		1
Interest rate and foreign exchange instruments	7		13		Interest Expense	1		1
					Other Income (Expense), Net	6		6
Total	$	34	$	187		$	24	$	(17)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

(1) Equity earnings at our foreign equity method investees are recognized after tax.

Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table

The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations.


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2023		2022		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	253	$	(151)	$	702	$	(228)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(20)		(4)		(47)		(4)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	(27)		(24)		(18)		(6)
Interest rate instrument	Interest Expense	—		—		(47)		—
Total		$	206	$	(179)	$	590	$	(238)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	(27)	$	(24)	$	(18)	$	(6)
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(20)	$	(4)	$	(47)	$	(4)

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

Revenue from Contract with Customer [Abstract]

DEBT AND CREDIT FACILITIES - NARRATIVE (Details)		1 Months Ended					6 Months Ended
DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	Mar. 20, 2023 USD ($)	Jun. 30, 2023 USD ($) bank	May 31, 2023 USD ($)	Mar. 31, 2023 USD ($)	Aug. 31, 2022 USD ($)	Jul. 31, 2022 USD ($)	Jun. 30, 2023 USD ($) bank lineOfCredit	Jun. 30, 2022 USD ($)	Mar. 21, 2023 USD ($)	Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 9,900,000,000					$ 9,900,000,000
Primary committed lines of credit \| lineOfCredit							8
Uncommitted letters of credit outstanding		514,000,000					$ 514,000,000
Issuances of debt (maturities greater than 90 days)							5,614,000,000	$ 4,818,000,000
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Amount available		32,000,000					32,000,000
Five Point Four Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 550,000,000					$ 550,000,000
Stated rate of debt (as a percent)		5.40%					5.40%
Proceeds from debt issuance		$ 545,000,000
Unamortized debt issuance costs		5,000,000					$ 5,000,000
Five Point Five Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 700,000,000					$ 700,000,000
Stated rate of debt (as a percent)		5.50%					5.50%
Proceeds from debt issuance		$ 692,000,000
Unamortized debt issuance costs		$ 8,000,000					$ 8,000,000
Sempra U.S.
Line of Credit Facility [Line Items]
Maximum ratio of indebtedness to total capitalization (as a percent)		65.00%					65.00%
SI Partners
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,000,000,000					$ 1,000,000,000
Maximum adjustment EBITDA allowed		5.25					5.25
SI Partners \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)	70.00%
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 200,000,000					$ 200,000,000
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity		200,000,000					200,000,000
Term of debt instrument (in years)				7 years
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000					$ 1,500,000,000
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate							1.05%
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Variable percentage rate		1.05%
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024 \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate		1.15%
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,200,000,000					$ 1,200,000,000
Issuances of debt (maturities greater than 90 days)							997,000,000	697,000,000
Debt issuance costs							9,000,000	6,000,000
Southern California Gas Company \| Term Loan Due 2023
Line of Credit Facility [Line Items]
Issuances of debt (maturities greater than 90 days)					$ 800,000,000
Southern California Gas Company \| Term Loan Due 2023 \| Secured Debt
Line of Credit Facility [Line Items]
Term of debt instrument (in years)						364 days
Variable percentage rate						0.70%
Debt amount						$ 800,000,000
Southern California Gas Company \| Five Point Two Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.20%
Proceeds from debt issuance			$ 495,000,000
Unamortized debt issuance costs			5,000,000
Southern California Gas Company \| Five Point Seven Five Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.75%
Proceeds from debt issuance			$ 493,000,000
Unamortized debt issuance costs			$ 7,000,000
Southern California Gas Company \| Senior Unsecured Floating Rate Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount		300,000,000					300,000,000
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000					1,500,000,000
Issuances of debt (maturities greater than 90 days)							792,000,000	1,395,000,000
Debt issuance costs							$ 9,000,000	$ 9,000,000
San Diego Gas and Electric Company \| Five Point Three Five Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount				$ 800,000,000
Stated rate of debt (as a percent)				5.35%
Proceeds from debt issuance				$ 783,000,000
Unamortized debt issuance costs				$ 17,000,000
Sempra LNG \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Term of debt instrument (in years)							5 years
Number of banks in syndicate \| bank		7					7
Weighted average interest rate (as a percent)		8.20%					8.20%			7.54%
Sempra Infrastructure \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,300,000,000					$ 1,300,000,000
Debt outstanding		708,000,000					$ 708,000,000			$ 575,000,000
IEnova \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							16.60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)	60.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable
Line of Credit Facility [Line Items]
Term of debt instrument (in years)				20 years
Debt amount		6,800,000,000					$ 6,800,000,000
Debt outstanding		$ 228,000,000					$ 228,000,000
Weighted average interest rate (as a percent)		5.58%					5.58%
Upfront equity funding amount				$ 4,700,000,000					$ 4,700,000,000
Debt issuance costs				$ 200,000,000
Commitment fee (in percent)				30.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)				60.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, Before Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate				2.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, After Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate				2.25%
SI Partners and ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Equity funding provided	$ 2,800,000,000
ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)	30.00%
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 4,000,000,000					$ 4,000,000,000

REVENUES

6 Months Ended

Jun. 30, 2023

We discuss revenue recognition for revenues from contracts with customers and from sources other than contracts with customers in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report.


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2023
By major service line:
Utilities	$	1,400	$	1,291	$	19	$	(34)	$	2,676
Energy-related businesses	—		—		235		(19)		216
Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892

By market:
Gas	$	252	$	1,291	$	167	$	(30)	$	1,680
Electric	1,148		—		87		(23)		1,212
Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892

Revenues from contracts with customers	$	1,400	$	1,291	$	254	$	(53)	$	2,892
Utilities regulatory revenues	(138)		176		—		—		38
Other revenues	—		—		406		(1)		405
Total revenues	$	1,262	$	1,467	$	660	$	(54)	$	3,335

	Six months ended June 30, 2023
By major service line:
Utilities	$	3,165	$	5,132	$	49	$	(72)	$	8,274
Energy-related businesses	—		—		547		(40)		507
Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781

By market:
Gas	$	806	$	5,132	$	371	$	(65)	$	6,244
Electric	2,359		—		225		(47)		2,537
Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781

Revenues from contracts with customers	$	3,165	$	5,132	$	596	$	(112)	$	8,781
Utilities regulatory revenues	(250)		129		—		—		(121)
Other revenues	—		—		1,260		(25)		1,235
Total revenues	$	2,915	$	5,261	$	1,856	$	(137)	$	9,895


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2022
By major service line:
Utilities	$	1,250	$	1,347	$	20	$	(27)	$	2,590
Energy-related businesses	—		—		457		(14)		443
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033

By market:
Gas	$	159	$	1,347	$	340	$	(19)	$	1,827
Electric	1,091		—		137		(22)		1,206
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033

Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Utilities regulatory revenues	149		154		—		—		303
Other revenues	—		—		212		(1)		211
Total revenues	$	1,399	$	1,501	$	689	$	(42)	$	3,547

	Six months ended June 30, 2022
By major service line:
Utilities	$	2,751	$	3,259	$	48	$	(56)	$	6,002
Energy-related businesses	—		—		749		(29)		720
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722

By market:
Gas	$	489	$	3,259	$	569	$	(45)	$	4,272
Electric	2,262		—		228		(40)		2,450
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722

Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Utilities regulatory revenues	93		235		—		—		328
Other revenues	—		—		316		1		317
Total revenues	$	2,844	$	3,494	$	1,113	$	(84)	$	7,367

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first six months of 2023)	$	175	$	2
2024	300		4
2025	338		4
2026	365		4
2027	365		4
Thereafter	4,077		59
Total revenues to be recognized	$	5,620	$	77

(1) Excludes intercompany transactions.

Contract Liabilities from Revenues from Contracts with Customers


CONTRACT LIABILITIES
(Dollars in millions)
	2023		2022
Sempra:
Contract liabilities at January 1	$	(252)	$	(278)
Revenue from performance obligations satisfied during reporting period	5		86
Payments received in advance	(2)		(105)
Contract liabilities at June 30(1)	$	(249)	$	(297)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(2)	$	(77)	$	(81)

(1) Balances at June 30, 2023 include $6 in Other Current Liabilities and $243 in Deferred Credits and Other.

(2) Balances at June 30, 2023 include $4 in Other Current Liabilities and $73 in Deferred Credits and Other.

Receivables from Revenues from Contracts with Customers

The table below shows receivable balances associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets.


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2023		December 31, 2022
Sempra:
Accounts receivable – trade, net(1)	$	1,828	$	2,291
Accounts receivable – other, net	14		25
Due from unconsolidated affiliates – current(2)	7		9
Other long-term assets(3)	3		9
Total	$	1,852	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	813	$	799
Accounts receivable – other, net	10		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	2		6
Total	$	831	$	819
SoCalGas:
Accounts receivable – trade, net	$	856	$	1,295
Accounts receivable – other, net	4		13
Other long-term assets(3)	1		3
Total	$	861	$	1,311

(1) At June 30, 2023 and December 31, 2022, includes $123 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

(2) Amount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists.

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 9
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-9

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 10
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-10

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 15
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-15

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-12

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479806/606-10-50-13

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Name Accounting Standards Codification
-Topic 606
-Publisher FASB
-URI https://asc.fasb.org//606/tableOfContent

Schedule of Regulatory Assets

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

REGULATORY MATTERS (Tables)

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	8	$	(110)
Deferred income taxes recoverable in rates	429		296
Pension and PBOP plan obligations	3		11
Removal obligations	(2,371)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	121		123
Regulatory balancing accounts(1)(2):
Commodity – electric	181		220
Gas transportation	7		60
Safety and reliability	158		107
Public purpose programs	(109)		(69)
Wildfire mitigation plan	519		375
Liability insurance premium	102		99
Other balancing accounts	(342)		(50)
Other regulatory assets, net(2)	153		137
Total SDG&E	(1,035)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	241		161
Pension and PBOP plan obligations	(232)		(170)
Employee benefit costs	24		24
Removal obligations	(591)		(616)
Environmental costs	37		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(362)		(257)
Safety and reliability	644		575
Public purpose programs	(152)		(158)
Liability insurance premium	22		23
Other balancing accounts	288		115
Other regulatory assets, net(2)	280		223
Total SoCalGas	199		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	5		—
Total Sempra Infrastructure	83		78
Total Sempra	$	(753)	$	(906)

(1) At June 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $748 and $562, respectively, and for SoCalGas was $859 and $692, respectively.

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

Schedule of Regulatory Liabilities


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	8	$	(110)
Deferred income taxes recoverable in rates	429		296
Pension and PBOP plan obligations	3		11
Removal obligations	(2,371)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	121		123
Regulatory balancing accounts(1)(2):
Commodity – electric	181		220
Gas transportation	7		60
Safety and reliability	158		107
Public purpose programs	(109)		(69)
Wildfire mitigation plan	519		375
Liability insurance premium	102		99
Other balancing accounts	(342)		(50)
Other regulatory assets, net(2)	153		137
Total SDG&E	(1,035)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	241		161
Pension and PBOP plan obligations	(232)		(170)
Employee benefit costs	24		24
Removal obligations	(591)		(616)
Environmental costs	37		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(362)		(257)
Safety and reliability	644		575
Public purpose programs	(152)		(158)
Liability insurance premium	22		23
Other balancing accounts	288		115
Other regulatory assets, net(2)	280		223
Total SoCalGas	199		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	5		—
Total Sempra Infrastructure	83		78
Total Sempra	$	(753)	$	(906)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

CPUC Authorized Cost of Capital and Rate Structure


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base(1)			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.05	%	1.83	%	Long-Term Debt	45.60	%	4.07	%	1.86	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		9.95		5.17		Common Equity	52.00		9.80		5.10
100.00	%			7.18	%		100.00	%			7.10	%

(1) Total weighted return on rate base does not sum due to rounding differences.

INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)

6 Months Ended

Jun. 30, 2023

Investments [Abstract]

Condensed Financial Statements

We provide summarized income statement information for Oncor Holdings in the following table.


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Operating revenues	$	1,343	$	1,293	$	2,635	$	2,542
Operating expenses	(976)		(908)		(2,000)		(1,805)
Income from operations	367		385		635		737
Interest expense	(133)		(108)		(256)		(216)
Income tax expense	(43)		(52)		(67)		(94)
Net income	197		226		296		417
Noncontrolling interest held by Texas Transmission Investment LLC	(40)		(46)		(60)		(84)
Earnings attributable to Sempra(1)	157		180		236		333

(1) Excludes adjustments to equity earnings related to amortization of a tax sharing liability associated with a tax sharing arrangement and changes in basis differences in AOCI within the carrying value of our equity method investment.

SAN ONOFRE NUCLEAR GENERATING STATION

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]

SAN ONOFRE NUCLEAR GENERATING STATION

REGULATORY MATTERS

We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report and provide updates to those discussions and information about new regulatory matters below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset.


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	8	$	(110)
Deferred income taxes recoverable in rates	429		296
Pension and PBOP plan obligations	3		11
Removal obligations	(2,371)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	121		123
Regulatory balancing accounts(1)(2):
Commodity – electric	181		220
Gas transportation	7		60
Safety and reliability	158		107
Public purpose programs	(109)		(69)
Wildfire mitigation plan	519		375
Liability insurance premium	102		99
Other balancing accounts	(342)		(50)
Other regulatory assets, net(2)	153		137
Total SDG&E	(1,035)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	241		161
Pension and PBOP plan obligations	(232)		(170)
Employee benefit costs	24		24
Removal obligations	(591)		(616)
Environmental costs	37		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(362)		(257)
Safety and reliability	644		575
Public purpose programs	(152)		(158)
Liability insurance premium	22		23
Other balancing accounts	288		115
Other regulatory assets, net(2)	280		223
Total SoCalGas	199		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	5		—
Total Sempra Infrastructure	83		78
Total Sempra	$	(753)	$	(906)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

SEMPRA CALIFORNIA

CPUC GRC

The CPUC uses GRCs to set revenues to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments.

In May 2022, SDG&E and SoCalGas filed their 2024 GRC applications requesting CPUC approval of test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. SDG&E and SoCalGas requested revenue requirements for 2024 of $3.0 billion and $4.4 billion, respectively. SDG&E and SoCalGas proposed post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. In October 2022, the CPUC issued a scoping ruling that set a schedule for the proceeding, including the expected issuance of a proposed decision in the second quarter of 2024. The CPUC has authorized SDG&E and SoCalGas to recognize the effects of the GRC final decision retroactive to January 1, 2024. SDG&E expects to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in the second half of 2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023. The results of the GRC may materially and adversely differ from what is contained in the GRC applications.

CPUC Cost of Capital

The CPUC approved the following cost of capital for SDG&E and SoCalGas that became effective on January 1, 2023 and will remain in effect through December 31, 2025, subject to the CCM. The CPUC will open a second phase of this cost of capital proceeding to evaluate the CCM.


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base(1)			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.05	%	1.83	%	Long-Term Debt	45.60	%	4.07	%	1.86	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		9.95		5.17		Common Equity	52.00		9.80		5.10
100.00	%			7.18	%		100.00	%			7.10	%

(1) Total weighted return on rate base does not sum due to rounding differences.

SDG&E

FERC Rate Matters

SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s currently effective TO5 settlement provides for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect until terminated by a notice provided at least six months before the end of the calendar year. Following such notice, SDG&E would file an updated rate request with an effective date of January 1 of the following year.

SAN ONOFRE NUCLEAR GENERATING STATION

We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that permanently ceased operations in June 2013, and in which SDG&E has a 20% ownership interest. We discuss SONGS further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.

NUCLEAR DECOMMISSIONING AND FUNDING

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored

on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal. SDG&E is responsible for approximately 20% of the total decommissioning cost.

In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra and SDG&E Condensed Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities.

Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In December 2022, the CPUC granted SDG&E authorization to access NDT funds of up to $81 million for forecasted 2023 costs.

The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Sempra and SDG&E Condensed Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 8.


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	40	$	1	$	(2)	$	39
Municipal bonds(2)	277		1		(12)		266
Other securities(3)	234		—		(16)		218
Total debt securities	551		2		(30)		523
Equity securities	104		222		(4)		322
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(6)		—		—		(6)
Total	$	673	$	224	$	(34)	$	863

	December 31, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	40	$	1	$	(1)	$	40
Municipal bonds	283		1		(14)		270
Other securities	248		—		(21)		227
Total debt securities	571		2		(36)		537
Equity securities	111		194		(8)		297
Short-term investments, primarily cash equivalents	11		—		—		11
Receivables (payables), net	(4)		—		—		(4)
Total	$	689	$	196	$	(44)	$	841

(1) Maturity dates are 2023-2053.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales.


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Proceeds from sales	$	138	$	155	$	294	$	397
Gross realized gains	6		3		8		14
Gross realized losses	(3)		(7)		(6)		(11)

Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.

ASSET RETIREMENT OBLIGATION

The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $523 million at June 30, 2023 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

Total due to unconsolidated affiliates – noncurrent

$ 26

$ 54

^[1]

(282)

(301)

^[1]

(5)

^[1]

Various affiliates

Tax Sharing Arrangement | Related Party

TAG Pipeline Norte | Related Party

(5)

San Diego Gas and Electric Company | Related Party

^[1]

San Diego Gas and Electric Company | Various affiliates

(43)

(135)

^[1]

San Diego Gas and Electric Company | Due to/from Sempra Energy

(14)

Income taxes due (to) from Sempra

(29)

(49)

(32)

San Diego Gas and Electric Company | Due to/from SoCalGas

(72)

Southern California Gas Company | Related Party

^[1]

Southern California Gas Company | Various affiliates

(36)

^[1]

Southern California Gas Company | Due to/from Sempra Energy

Income taxes due (to) from Sempra

(36)

(11)

(16)

Southern California Gas Company | Due to/from SDG&E

Sempra Infrastructure | Related Party

Total due to unconsolidated affiliates – noncurrent

$ (282)

(301)

Five Point Five Percent Note Due January 2024 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ 0

(40)

Five Point Five Percent Note Due January 2025 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (23)

(23)

Five Point Five Percent Notes Due July 2025 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (22)

(21)

Five Point Five Percent Note due January 2026 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (19)

(19)

Five Point Five Percent Note due July 2026 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (11)

(11)

Five Point Five Percent Note due January 2027 | Sempra Infrastructure | TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (14)

Five Point Seven Four Percent Note December 2029 | Sempra Infrastructure | TAG | Related Party

Total due to unconsolidated affiliates – noncurrent

5.74%

$ (193)

$ (187)

[1]	Derived from audited financial statements.

DEBT AND CREDIT FACILITIES

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

DEBT AND CREDIT FACILITIES

The principal terms of our debt arrangements are described below and in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

SHORT-TERM DEBT

Committed Lines of Credit

At June 30, 2023, Sempra had an aggregate capacity of $9.9 billion under eight primary committed lines of credit, which provide liquidity and support commercial paper programs. Because our commercial paper programs are supported by some of these lines of credit, we reflect the amount of commercial paper outstanding, before reductions of any unamortized discounts, and any letters of credit outstanding as a reduction to the available unused credit capacity in the following table.


COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Letters of credit outstanding		Available unused credit
Sempra	October 2027	$	4,000	$	(813)	$	—	$	—	$	3,187
SDG&E	October 2027	1,500		—		—		—		1,500
SoCalGas	October 2027	1,200		(238)		—		—		962
SI Partners	November 2024	1,000		—		—		—		1,000
IEnova and SI Partners	September 2023	350		—		(350)		—		—
IEnova and SI Partners	December 2023	150		—		—		—		150
IEnova and SI Partners	February 2024	1,500		—		(1,086)		—		414
Port Arthur LNG	March 2030	200		—		—		(15)		185
Total		$	9,900	$	(1,051)	$	(1,436)	$	(15)	$	7,398

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At June 30, 2023, each entity was in compliance with this ratio under its respective credit facility.

SI Partners must maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in its credit facilities) of no more than 5.25 to 1.00 at the end of each quarter. At June 30, 2023, SI Partners was in compliance with this ratio.

In March 2023, Port Arthur LNG entered into a seven-year initial working capital facility agreement with a syndicate of lenders expiring in March 2030. The credit facility permits borrowings of up to $200 million, which bear interest by reference to Term SOFR, plus the applicable margin and a credit adjustment spread. The credit facility also provides for the issuance of up to $200 million of letters of credit.

Uncommitted Line of Credit

ECA LNG Phase 1 has an uncommitted line of credit, which is generally used for working capital requirements, with an aggregate capacity of $200 million of which $32 million was outstanding at June 30, 2023. The amounts outstanding are before reductions of any unamortized discounts. Borrowings can be in U.S. dollars or Mexican pesos. At June 30, 2023, outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps. In June 2023, the facility was amended to extend the expiration date to August 2024 and replace the LIBOR reference rate plus 105 bps with the SOFR reference rate plus 115 bps. As such, borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month SOFR plus 115 bps.

Uncommitted Letters of Credit

Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At June 30, 2023, we had $514 million in standby letters of credit outstanding under these agreements.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		June 30, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2024 - May 2024	$	15
SoCalGas	November 2023 - October 2024	20
Sempra Infrastructure	July 2023 - October 2043	311
Parent and other	September 2023 - June 2024	168
Total		$	514

Term Loan

In July 2022, SoCalGas entered into an $800 million, 364-day term loan agreement with a maturity date of July 6, 2023. In August 2022, SoCalGas borrowed $800 million, net of negligible debt issuance costs, under the term loan agreement. The borrowing bore interest at benchmark rates plus 70 bps and was due in full upon maturity. SoCalGas used the proceeds for payment of a portion of the costs relating to litigation pertaining to the Leak. In the second quarter of 2023, SoCalGas repaid the term loan in full.

Weighted-Average Interest Rates

The weighted-average interest rates on all short-term debt were as follows:


WEIGHTED-AVERAGE INTEREST RATES

	June 30, 2023		December 31, 2022
Sempra	5.92	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.14		4.71

LONG-TERM DEBT

SDG&E

In March 2023, SDG&E issued $800 million aggregate principal amount of 5.35% first mortgage bonds due in full upon maturity on April 1, 2053 and received proceeds of $783 million (net of debt discount, underwriting discounts and debt issuance costs of $17 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SDG&E used the net proceeds for general corporate purposes, including repayment of commercial paper and other indebtedness.

SoCalGas

In May 2023, SoCalGas issued $500 million aggregate principal amount of 5.20% first mortgage bonds due in full upon maturity on June 1, 2033 and received proceeds of $495 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $500 million aggregate principal amount of 5.75% first mortgage bonds due in full upon maturity on June 1, 2053 and received proceeds of $493 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). Each series of first mortgage bonds is redeemable prior to maturity, subject to its terms, and in certain circumstances subject to make-whole provisions. SoCalGas used the net proceeds to repay its $300 million senior unsecured floating rate notes prior to their September 2023 scheduled maturity, a portion of its $800 million term loan and other general corporate purposes.

Sempra

In June 2023, Sempra issued $550 million aggregate principal amount of 5.40% senior unsecured notes due in full upon maturity on August 1, 2026 and received proceeds of $545 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $700 million aggregate principal amount of 5.50% senior unsecured notes due in full upon maturity on August 1, 2033 and received proceeds of $692 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). Each series of notes is redeemable prior to maturity, subject to its terms, and in certain circumstances subject to make-whole provisions. We intend to use the net proceeds for general corporate purposes, including repayment of commercial paper and potentially other indebtedness.

Sempra Infrastructure

ECA LNG Phase 1

ECA LNG Phase 1 has a five-year loan agreement with a syndicate of seven external lenders that matures in December 2025 for an aggregate principal amount of up to $1.3 billion. IEnova and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest of 83.4% and 16.6%, respectively. At June 30, 2023 and December 31, 2022, $708 million and $575 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 8.20% and 7.54%, respectively.

Port Arthur LNG

In March 2023, Port Arthur LNG entered into a term loan facility agreement with a syndicate of lenders for an aggregate principal amount of approximately $6.8 billion. Proceeds from the loans will be used to finance the cost of construction of the PA LNG Phase 1 project. The loans mature on March 20, 2030 and bear interest by reference to Term SOFR, plus the applicable margin and a credit adjustment spread. The applicable margin prior to completion of the PA LNG Phase 1 project (which occurs upon the satisfaction or waiver of a series of customary operational, technical, environmental and social and other tests and conditions that generally would not be fully met until after the commercial operations date) is 2.00% and on completion and thereafter is 2.25%. The principal amounts outstanding on the loans must be repaid in quarterly installments, commencing on the earlier of (i) the first quarterly payment date occurring more than three calendar months following completion of the PA LNG Phase 1 project and (ii) April 20, 2029. Under the terms of the loan agreement, at least 60% of the projected outstanding balance is required to be hedged during construction and over the underlying 20-year notional amortization period. As we discuss in Note 7, Port Arthur LNG entered into hedging instruments in satisfaction of this requirement in March 2023. An upfront equity funding amount of $4.7 billion is required to have been contributed to Port Arthur LNG for construction costs as a condition to the initial advance of term loans under the agreement (other than advances for fees, interest, expenses and certain other specified costs). Port Arthur LNG paid $200 million in debt issuance costs at closing. Additionally, the loan agreement and the related working capital facility agreement that we discuss above require payment of commitment fees calculated at a rate per annum equal to 30% of the applicable margin for Term SOFR loans multiplied by the outstanding debt commitments, and additional administrative fees. At June 30, 2023, $228 million of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.58%.

In connection with this loan agreement, SI Partners and ConocoPhillips have collectively provided commitments for approximately $2.8 billion in equity funding for the benefit of Port Arthur LNG for their respective affiliate’s share of the equity funding of anticipated construction costs of the PA LNG Phase 1 project in excess of the upfront equity funding amount of $4.7 billion. The amount of each commitment is based on each of SI Partners’ and ConocoPhillips’ proportionate indirect ownership interest in Port Arthur LNG of 70% and 30%, respectively. The obligation under these guarantees will be reduced as their respective affiliates fund their direct proportionate interest of capital calls. Such equity funding can be called upon by Port Arthur LNG to fund project costs or, upon the taking of an enforcement action under the terms of Port Arthur LNG’s finance documents, to pay its senior debt obligations.

The pari passu secured obligations under the related finance documents are secured by a first priority lien (subject to customary permitted encumbrances) in substantially all of the assets of Port Arthur LNG, including the equity interests in, and real property

interests of, Port Arthur LNG.

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
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-Name Accounting Standards Codification
-Section 50
-Paragraph 1B
-Subparagraph (h)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1B

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
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-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
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-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
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-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

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

REGULATORY MATTERS - FERC RATE MATTERS (Details) - San Diego Gas and Electric Company	6 Months Ended
	Jun. 30, 2023
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
FERC requirement, additional basis spread	0.50%

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

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

Inventory [Line Items]

Natural gas

$ 87

$ 106

LNG

Materials and supplies

279

235

Total

383

403

^[1]

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

142

133

Total

143

134

^[1]

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

117

Total

$ 180

$ 159

^[1]

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS (Details) - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

Dedicated assets in support of certain benefit plans

$ 520

$ 505

^[1]

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 175	$ 80	$ 551	$ 414
Income before income taxes and equity earnings	523	364	1,852	1,029
Equity earnings, before income tax:	153	159	285	302
Pretax income	$ 676	$ 523	$ 2,137	$ 1,331
Effective income tax rate (as a percent)	26.00%	15.00%	26.00%	31.00%
San Diego Gas and Electric Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 4	$ 42	$ 11	$ 106
Income before income taxes and equity earnings	$ 188	$ 218	$ 453	$ 516
Effective income tax rate (as a percent)	2.00%	19.00%	2.00%	21.00%
Southern California Gas Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (21)	$ 19	$ 73	$ 103
Income before income taxes and equity earnings	$ 135	$ 107	$ 589	$ 525
Effective income tax rate (as a percent)	(16.00%)	18.00%	12.00%	20.00%

Amount of income (loss) from continuing operations, including income (loss) from equity method investments, before deduction of income tax expense (benefit), and income (loss) attributable to noncontrolling interest.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Paragraph 1
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

Segment Reporting Information, Profit (Loss) [Abstract]

SEGMENT INFORMATION - SCHEDULE (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2023

Jun. 30, 2022

Jun. 30, 2023

Jun. 30, 2022

Dec. 31, 2022

$ 3,335

$ 3,547

$ 9,895

$ 7,367

549

501

1,088

994

317

271

683

514

Equity earnings, before income tax:

175

551

414

153

159

285

302

Equity earnings, net of income tax:

235

216

322

399

Equity earnings

388

375

607

701

Segment Reporting Information, Additional Information [Abstract]

603

559

1,572

1,171

4,282

2,361

EQUITY METHOD INVESTMENTS

82,727

$ 78,574

^[1]

16,015

15,677

Operating Segments | SDG&E

Segment Reporting Information, Profit (Loss) [Abstract]

1,262

1,399

2,915

2,844

268

244

530

483

123

114

241

220

106

Segment Reporting Information, Additional Information [Abstract]

184

176

442

410

1,239

1,090

Operating Segments | SoCalGas

27,786

26,422

Segment Reporting Information, Profit (Loss) [Abstract]

1,467

1,501

5,261

3,494

208

188

414

375

140

(21)

103

Segment Reporting Information, Additional Information [Abstract]

155

515

421

961

931

Operating Segments | Sempra Texas Utilities

22,591

22,346

Segment Reporting Information, Profit (Loss) [Abstract]

Equity earnings, before income tax:

Equity earnings, net of income tax:

160

184

243

346

Segment Reporting Information, Additional Information [Abstract]

160

186

243

348

EQUITY METHOD INVESTMENTS

13,988

13,781

13,979

13,772

Operating Segments | Sempra Infrastructure

Segment Reporting Information, Profit (Loss) [Abstract]

660

689

1,856

1,113

139

132

120

Equity earnings, before income tax:

201

531

161

151

156

282

297

Equity earnings, net of income tax:

Segment Reporting Information, Additional Information [Abstract]

208

183

523

278

2,078

336

EQUITY METHOD INVESTMENTS

17,610

15,760

2,036

1,905

Adjustments and eliminations

Segment Reporting Information, Profit (Loss) [Abstract]

Segment Reporting Information, Profit (Loss) [Abstract]

(2)

(1)

All other

183

151

(9)

(51)

(64)

Segment Reporting Information, Additional Information [Abstract]

(104)

(73)

(151)

(286)

Intersegment revenues and eliminations

1,773

1,376

Segment Reporting Information, Profit (Loss) [Abstract]

(52)

(40)

(136)

(84)

Segment Reporting Information, Additional Information [Abstract]

(1)

Intersegment revenues and eliminations | SDG&E

(1,021)

$ (1,111)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues and eliminations | SoCalGas

(5)

(3)

(9)

(7)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues and eliminations | Sempra Infrastructure

(28)

(23)

(62)

(49)

Segment Reporting Information, Profit (Loss) [Abstract]

Beginning Balance at Dec. 31, 2021

$ (19)

$ (14)

$ (65)

$ (28)

[1]	Derived from audited financial statements.

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas - USD ($)
$ in Millions

Total

Preferred stock

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

Southern California Gas Company

Preferred stock

Southern California Gas Company

Common stock

Southern California Gas Company

Retained earnings

Southern California Gas Company

Accumulated other comprehensive income (loss)

$ 27,419

$ 889

$ 11,862

$ 13,548

$ (318)

$ 5,442

$ 22

$ 1,666

$ 3,785

$ (31)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,316

1,194

422

178

142

Equity contribution from Sempra

(1)

150

Beginning Balance at Mar. 31, 2022

29,053

889

12,121

13,998

(167)

6,015

1,816

4,206

(29)

27,560

889

11,656

13,798

(229)

5,777

1,666

4,119

(30)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

659

571

Equity contribution from Sempra

(1)

150

Beginning Balance at Dec. 31, 2022

29,053

889

12,121

13,998

(167)

6,015

1,816

4,206

(29)

29,256

^[1]

889

12,160

14,201

(135)

6,698

2,316

4,384

(24)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

1,908

1,595

516

(1)

Beginning Balance at Mar. 31, 2023

31,014

889

12,044

15,024

(121)

7,215

2,316

4,899

(22)

30,245

889

12,164

14,796

(182)

7,059

2,316

4,744

(23)

Increase (Decrease) in Stockholders' Equity [Roll Forward]

736

615

156

117

(1)

$ 31,014

$ 889

$ 12,044

$ 15,024

$ (121)

$ 7,215

$ 22

$ 2,316

$ 4,899

$ (22)

[1]	Derived from audited financial statements.

Amount after tax and reclassification adjustments of other comprehensive income (loss).

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-SubTopic 10
-Topic 505
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481112/505-10-50-2

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 830
-SubTopic 30
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481674/830-30-50-1

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 830
-SubTopic 30
-Name Accounting Standards Codification
-Section 45
-Paragraph 17
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481694/830-30-45-17

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04(19))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483586/944-220-S99-1

Reference 5: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482765/220-10-50-4

Reference 6: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 5
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482765/220-10-50-5

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 830
-SubTopic 30
-Name Accounting Standards Codification
-Section 45
-Paragraph 20
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481694/830-30-45-20

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(21))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483621/220-10-S99-2

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 942
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(23))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483589/942-220-S99-1

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 1B
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482790/220-10-45-1B

Reference 11: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Section 55
-Paragraph 15
-SubTopic 10
-Topic 220
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482739/220-10-55-15

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 1A
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482790/220-10-45-1A

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

Amount of equity (deficit) attributable to parent and noncontrolling interest. Excludes temporary equity.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS - OTHER NONCONTROLLING INTERESTS (Details) - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

SI Partners | Sempra Infrastructure

$ 3,158

$ 2,121

^[1]

Ownership interest (as a percent)

30.00%

SI Partners subsidiaries | Sempra Infrastructure

$ 2,424

$ 2,060

SI Partners subsidiaries | Sempra Infrastructure | Minimum

$ 734

$ 61

Ownership interest (as a percent)

0.10%

SI Partners subsidiaries | Sempra Infrastructure | Maximum

Ownership interest (as a percent)

30.00%

16.60%

[1]	Derived from audited financial statements.

SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Segment Information


SEGMENT INFORMATION
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
REVENUES
SDG&E	$	1,262	$	1,399	$	2,915	$	2,844
SoCalGas	1,467		1,501		5,261		3,494
Sempra Infrastructure	660		689		1,856		1,113
Adjustments and eliminations	(2)		(2)		(1)		—
Intersegment revenues(1)	(52)		(40)		(136)		(84)
Total	$	3,335	$	3,547	$	9,895	$	7,367
DEPRECIATION AND AMORTIZATION
SDG&E	$	268	$	244	$	530	$	483
SoCalGas	208		188		414		375
Sempra Infrastructure	70		67		139		132
All other	3		2		5		4
Total	$	549	$	501	$	1,088	$	994
INTEREST INCOME
SDG&E	$	4	$	1	$	5	$	1
SoCalGas	1		1		5		1
Sempra Infrastructure	6		9		21		30
All other	6		4		10		8
Total	$	17	$	15	$	41	$	40
INTEREST EXPENSE
SDG&E	$	123	$	114	$	241	$	220
SoCalGas	71		45		140		85
Sempra Infrastructure	25		32		120		59
All other	99		81		183		151
Intercompany eliminations	(1)		(1)		(1)		(1)
Total	$	317	$	271	$	683	$	514
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	4	$	42	$	11	$	106
SoCalGas	(21)		19		73		103
Sempra Infrastructure	201		70		531		161
All other	(9)		(51)		(64)		44
Total	$	175	$	80	$	551	$	414
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	3	$	3	$	5
Sempra Infrastructure	151		156		282		297

	153		159		285		302
Equity earnings, net of income tax:
Sempra Texas Utilities	160		184		243		346
Sempra Infrastructure	75		32		79		53
	235		216		322		399
Total	$	388	$	375	$	607	$	701


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	184	$	176	$	442	$	410
SoCalGas	155		87		515		421
Sempra Texas Utilities	160		186		243		348
Sempra Infrastructure	208		183		523		278
All other	(104)		(73)		(151)		(286)
Total	$	603	$	559	$	1,572	$	1,171
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,239	$	1,090
SoCalGas					961		931
Sempra Infrastructure					2,078		336
All other					4		4
Total					$	4,282	$	2,361

					June 30, 2023		December 31, 2022
ASSETS
SDG&E					$	27,786	$	26,422
SoCalGas					22,591		22,346
Sempra Texas Utilities					13,988		13,781
Sempra Infrastructure					17,610		15,760
All other					1,773		1,376
Intersegment receivables					(1,021)		(1,111)
Total					$	82,727	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities					$	13,979	$	13,772
Sempra Infrastructure					2,036		1,905
Total					$	16,015	$	15,677

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

DERIVATIVE FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that could cause our asset values to fall or our liabilities to increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not included in the tables below.

In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below.

In all other cases, we record derivatives at fair value on the Condensed Consolidated Balance Sheets. We may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for SDG&E and SoCalGas and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges and undesignated derivatives not subject to rate recovery). We classify cash flows from the principal settlements of cross-currency swaps that hedge exposure related to Mexican peso-denominated debt and amounts related to terminations or early settlements of interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows.

HEDGE ACCOUNTING

We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk of variability of future cash flows of a given revenue or expense item, and other criteria.

ENERGY DERIVATIVES

Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows:

▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power.

▪SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations.

▪Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations.

▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other derivatives to hedge exposures such as GHG allowances.

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

June 30, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

380

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

271

224

INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings.

In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for

construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap.

As we discuss in Note 6, a minimum of 60% of the projected amount of term loans outstanding is required to be hedged under the Port Arthur LNG term loan facility agreement. In March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps with 17 counterparties to hedge the variability in cash flows related to the SOFR-based component of interest payments on forecasted loans outstanding under the agreement. The notional amounts of the interest rate swaps generally increase in proportion to the forecasted borrowings up to a maximum amount of $4.2 billion prior to the maturity of the term loans on March 20, 2030. Under the interest rate swaps, which are designated as cash flow hedges, Port Arthur LNG receives interest at Term SOFR and pays interest at a fixed rate of 3.23% based on amortizing notional amounts maturing in 2048.

The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments and the contingent interest rate swap.

INTEREST RATE DERIVATIVES

(Dollars in millions)

June 30, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,454

2023-2048

294

2023-2034

(1) At June 30, 2023 and December 31, 2022, cash flow hedges accrued interest based on a notional of $491 and $294, respectively.

FOREIGN CURRENCY DERIVATIVES

We may utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican fixed interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar.

We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation.

The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments.


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	June 30, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	65		2023-2024	111		2023-2024

FINANCIAL STATEMENT PRESENTATION

The Condensed Consolidated Balance Sheets reflect the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions.


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	16	$	46	$	—	$	(2)
Foreign exchange instruments	—		—		(15)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	251		35		(236)		(42)
Associated offsetting commodity contracts	(232)		(35)		232		35
Commodity contracts subject to rate recovery	20		17		(64)		(17)
Associated offsetting commodity contracts	(12)		(4)		12		4
Associated offsetting cash collateral	—		—		10		4
Net amounts presented on the balance sheet	43		59		(61)		(18)
Additional cash collateral for commodity contracts not subject to rate recovery	143		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	70		—		—		—
Total(2)	$	256	$	59	$	(61)	$	(18)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	18	$	17	$	(26)	$	(8)
Associated offsetting commodity contracts	(11)		(4)		11		4
Associated offsetting cash collateral	—		—		10		4
Net amounts presented on the balance sheet	7		13		(5)		—
Additional cash collateral for commodity contracts subject to rate recovery	69		—		—		—
Total(2)	$	76	$	13	$	(5)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	2	$	—	$	(38)	$	(9)
Associated offsetting commodity contracts	(1)		—		1		—
Net amounts presented on the balance sheet	1		—		(37)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	2	$	—	$	(37)	$	(9)

(1) Included in Other Current Assets for SoCalGas.

(2) Normal purchase contracts previously measured at fair value are excluded.


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2022
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	10	$	33	$	—	$	—
Foreign exchange instruments	—		—		(7)		(1)
Interest rate and foreign exchange instruments	—		—		(105)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	480		133		(399)		(132)
Associated offsetting commodity contracts	(301)		(39)		301		39
Commodity contracts subject to rate recovery	138		27		(97)		(2)
Associated offsetting commodity contracts	(27)		(2)		27		2
Interest rate instrument	33		—		—		—
Net amounts presented on the balance sheet	333		152		(280)		(94)
Additional cash collateral for commodity contracts not subject to rate recovery	451		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total(2)	$	802	$	152	$	(280)	$	(94)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	107	$	27	$	(13)	$	(2)
Associated offsetting commodity contracts	(12)		(2)		12		2
Net amounts presented on the balance sheet	95		25		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	17		—		—		—
Total(2)	$	112	$	25	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	31	$	—	$	(84)	$	—
Associated offsetting commodity contracts	(15)		—		15		—
Net amounts presented on the balance sheet	16		—		(69)		—
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	17	$	—	$	(69)	$	—

(1) Included in Other Current Assets for SoCalGas.

(2) Normal purchase contracts previously measured at fair value are excluded.

The following table includes the effects of derivative instruments designated as cash flow hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI.


CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	94	$	13	Interest Expense	$	—	$	—
Interest rate instruments	41		50		Equity Earnings(1)	14		(13)
Foreign exchange instruments	(2)		—		Revenues: Energy- Related Businesses	—		1
					Other Income (Expense), Net	(1)		(1)
Foreign exchange instruments	(1)		—		Equity Earnings(1)	(1)		—
Interest rate and foreign exchange instruments	—		4		Interest Expense	1		1

Total	$	132	$	67		$	13	$	(12)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

	Six months ended June 30,					Six months ended June 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	17	$	35	Interest Expense	$	—	$	1
Interest rate instruments	24		144		Equity Earnings(1)	21		(27)
Foreign exchange instruments	(8)		(3)		Revenues: Energy- Related Businesses	—		2
					Other Income (Expense), Net	(2)		(1)
Foreign exchange instruments	(6)		(2)		Equity Earnings(1)	(2)		1
Interest rate and foreign exchange instruments	7		13		Interest Expense	1		1
					Other Income (Expense), Net	6		6
Total	$	34	$	187		$	24	$	(17)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

(1) Equity earnings at our foreign equity method investees are recognized after tax.

For Sempra, we expect that net gains before NCI of $23 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $14 million attributable to NCI) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at June 30, 2023 is approximately 25 years for Sempra. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 16 years.

The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations.


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2023		2022		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	253	$	(151)	$	702	$	(228)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(20)		(4)		(47)		(4)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	(27)		(24)		(18)		(6)
Interest rate instrument	Interest Expense	—		—		(47)		—
Total		$	206	$	(179)	$	590	$	(238)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	(27)	$	(24)	$	(18)	$	(6)
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(20)	$	(4)	$	(47)	$	(4)

CREDIT RISK RELATED CONTINGENT FEATURES

For Sempra, SDG&E and SoCalGas, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization.

For Sempra, the total fair value of this group of derivative instruments in a liability position at June 30, 2023 and December 31, 2022 was $50 million and $106 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at June 30, 2023 and December 31, 2022 was $46 million and $69 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at June 30, 2023 or December 31, 2022. At June 30, 2023, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $50 million and $46 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

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.

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

6 Months Ended

Jun. 30, 2023

Public Utilities, General Disclosures [Abstract]

Schedule of Nuclear Decommissioning Trusts Investments


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	40	$	1	$	(2)	$	39
Municipal bonds(2)	277		1		(12)		266
Other securities(3)	234		—		(16)		218
Total debt securities	551		2		(30)		523
Equity securities	104		222		(4)		322
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(6)		—		—		(6)
Total	$	673	$	224	$	(34)	$	863

	December 31, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	40	$	1	$	(1)	$	40
Municipal bonds	283		1		(14)		270
Other securities	248		—		(21)		227
Total debt securities	571		2		(36)		537
Equity securities	111		194		(8)		297
Short-term investments, primarily cash equivalents	11		—		—		11
Receivables (payables), net	(4)		—		—		(4)
Total	$	689	$	196	$	(44)	$	841

(1) Maturity dates are 2023-2053.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

Schedule of Sales of Securities By Nuclear Decommissioning Trusts

The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales.


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Proceeds from sales	$	138	$	155	$	294	$	397
Gross realized gains	6		3		8		14
Gross realized losses	(3)		(7)		(6)		(11)

Tabular disclosure of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale).

Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 9
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-9

Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 4: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 5: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 6: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (aa)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 7: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (aaa)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 8: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-2

Reference 9: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 10: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 11: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Reference 12: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 320
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481800/320-10-50-3

Commitments and Contingencies Disclosure [Abstract]

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

COMMITMENTS AND CONTINGENCIES (Tables)

6 Months Ended

Jun. 30, 2023

Schedule of Operating Lease Payments Received, Lease Income Table

We provide information below for leases for which we are the lessor.


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sales-type leases:

Interest income	$	1	$	2	$	3	$	4
Total revenues from sales-type leases(1)	$	1	$	2	$	3	$	4

Operating leases:
Fixed lease payments	$	76	$	70	$	156	$	140
Variable lease payments	14		3		16		4
Total revenues from operating leases(1)	$	90	$	73	$	172	$	144

Depreciation expense	$	15	$	14	$	30	$	27

(1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations.

Sales-type Lease, Lease Income

We provide information below for leases for which we are the lessor.


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sales-type leases:

Interest income	$	1	$	2	$	3	$	4
Total revenues from sales-type leases(1)	$	1	$	2	$	3	$	4

Operating leases:
Fixed lease payments	$	76	$	70	$	156	$	140
Variable lease payments	14		3		16		4
Total revenues from operating leases(1)	$	90	$	73	$	172	$	144

Depreciation expense	$	15	$	14	$	30	$	27

(1) Included in Revenues: Energy-Related Businesses on the Condensed Consolidated Statements of Operations.

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS & ENVIRONMENTAL ISSUES (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Loss Contingencies [Line Items]
Potential monetary sanctions threshold	$ 1
Potential monetary sanctions threshold (as a percent)	1.00%
Environmental cost, potential monetary sanctions threshold, actual amount	$ 48
Sempra Infrastructure \| Natural Gas Storage and Transportation Contracts
Loss Contingencies [Line Items]
Change since 2022	863
Change in 2023	(27)
Change in 2024	23
Change in 2025	33
Change in 2026	33
Change in 2027	30
Change thereafter	771
Sempra Infrastructure \| Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Change in 2023	(841)
Change in 2024	(87)
Change in 2025	(65)
Change in 2026	(87)
Change in 2027	(98)
Change thereafter	(208)
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	17
Southern California Gas Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	$ 13

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)

6 Months Ended

Jun. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash and Cash Equivalents


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2023		December 31, 2022
Cash and cash equivalents	$	1,077	$	370
Restricted cash, current	74		40
Restricted cash, noncurrent	91		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	1,242	$	462

Accounts Receivable, Allowance for Credit Loss Table


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2023		2022
Sempra:
Allowances for credit losses at January 1	$	181	$	136
Provisions for expected credit losses	228		77
Write-offs	(43)		(36)
Allowances for credit losses at June 30	$	366	$	177
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	63		37
Write-offs	(23)		(18)
Allowances for credit losses at June 30	$	118	$	85
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	164		37
Write-offs	(20)		(18)
Allowances for credit losses at June 30	$	242	$	88

Allowances for credit losses related to trade receivables and other receivables are included in the Condensed Consolidated Balance Sheets as follows:


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	320	$	140
Accounts receivable – other, net	46		40
Other long-term assets	—		1
Total allowances for credit losses	$	366	$	181
SDG&E:
Accounts receivable – trade, net	$	91	$	52
Accounts receivable – other, net	27		25
Other long-term assets	—		1
Total allowances for credit losses	$	118	$	78
SoCalGas:
Accounts receivable – trade, net	$	223	$	83
Accounts receivable – other, net	19		15
Total allowances for credit losses	$	242	$	98

Inventory Table

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022
Natural gas	$	87	$	106	$	1	$	1	$	63	$	74
LNG	17		62		—		—		—		—
Materials and supplies	279		235		142		133		117		85
Total	$	383	$	403	$	143	$	134	$	180	$	159

Capitalized Financing Costs Table

The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest.


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra	$	110	$	60	$	183	$	117
SDG&E	31		26		62		54
SoCalGas	20		17		35		35

Net Periodic Benefit Cost Table


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	29	$	42	$	3	$	6
Interest cost	39		29		10		7
Expected return on assets	(42)		(45)		(18)		(16)
Amortization of:
Prior service cost	1		2		—		—
Actuarial loss (gain)	2		5		(6)		(3)
Net periodic benefit cost (credit)	29		33		(11)		(6)
Regulatory adjustments	29		24		11		6
Total expense recognized	$	58	$	57	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	57	$	83	$	7	$	13
Interest cost	79		59		19		14
Expected return on assets	(85)		(91)		(35)		(32)
Amortization of:
Prior service cost (credit)	2		5		(1)		(1)
Actuarial loss (gain)	4		11		(12)		(7)
Net periodic benefit cost (credit)	57		67		(22)		(13)
Regulatory adjustments	58		(3)		22		13
Total expense recognized	$	115	$	64	$	—	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	8	$	10	$	—	$	1
Interest cost	10		6		2		2
Expected return on assets	(10)		(11)		(2)		(3)
Amortization of:
Actuarial loss	1		1		—		—
Net periodic benefit cost	9		6		—		—
Regulatory adjustments	4		7		—		—
Total expense recognized	$	13	$	13	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	16	$	20	$	1	$	3
Interest cost	20		13		4		3
Expected return on assets	(20)		(22)		(4)		(5)
Amortization of:
Actuarial loss (gain)	2		1		(1)		(1)
Net periodic benefit cost	18		12		—		—
Regulatory adjustments	8		2		—		—
Total expense recognized	$	26	$	14	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2023		2022		2023		2022
Service cost	$	17	$	28	$	2	$	5
Interest cost	26		21		7		6
Expected return on assets	(31)		(33)		(15)		(14)
Amortization of:
Prior service cost	1		2		—		—
Actuarial loss (gain)	—		4		(5)		(3)
Net periodic benefit cost (credit)	13		22		(11)		(6)
Regulatory adjustments	25		17		11		6
Total expense recognized	$	38	$	39	$	—	$	—

	Six months ended June 30,
	2023		2022		2023		2022
Service cost	$	34	$	56	$	5	$	10
Interest cost	51		41		14		11
Expected return on assets	(60)		(64)		(30)		(27)
Amortization of:
Prior service cost (credit)	2		4		(1)		(1)
Actuarial loss (gain)	—		8		(10)		(6)
Net periodic benefit cost (credit)	27		45		(22)		(13)
Regulatory adjustments	50		(5)		22		13
Total expense recognized	$	77	$	40	$	—	$	—

Earnings Per Share Computations Table


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	315,007		314,845		314,963		315,595
Dilutive effect of stock options and RSUs(2)	1,053		1,022		1,129		1,052
Weighted-average common shares outstanding for diluted EPS	316,060		315,867		316,092		316,647

EPS:
Basic	$	1.91	$	1.78	$	4.99	$	3.71
Diluted	$	1.91	$	1.77	$	4.97	$	3.70

The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented:


PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	630,014		629,691		629,926		631,190
Dilutive effect of stock options and RSUs	2,107		2,044		2,259		2,104
Weighted-average common shares outstanding for diluted EPS	632,121		631,735		632,185		633,294

EPS:
Basic	$	0.96	$	0.89	$	2.50	$	1.86
Diluted	$	0.95	$	0.89	$	2.49	$	1.85

Schedule of Accumulated Other Comprehensive Income (Loss) Table

The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, after amounts attributable to NCI.


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Three months ended June 30, 2023 and 2022
Sempra:
Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)
OCI before reclassifications	11		53		—		64
Amounts reclassified from AOCI	—		(4)		1		(3)
Net OCI	11		49		1		61
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)

Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
OCI before reclassifications	1		37		1		39
Amounts reclassified from AOCI(2)	10		11		2		23
Net OCI(2)	11		48		3		62
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
SDG&E:
Balance at March 31, 2023 and June 30, 2023					$	(7)	$	(7)





Balance at March 31, 2022 and June 30, 2022					$	(10)	$	(10)

SoCalGas:
Balance at March 31, 2023			$	(12)	$	(11)	$	(23)

Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

Balance at March 31, 2022			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)

(1) All amounts are net of income tax, if subject to tax, and after NCI.


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Six months ended June 30, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	21		13		(13)		21
Amounts reclassified from AOCI	—		(9)		2		(7)
Net OCI	21		4		(11)		14
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		111		7		122
Amounts reclassified from AOCI(2)	10		15		4		29
Net OCI(2)	14		126		11		151
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
SDG&E:
Balance at December 31, 2022 and June 30, 2023					$	(7)	$	(7)





Balance at December 31, 2021 and June 30, 2022					$	(10)	$	(10)




SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)

Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)

(1) All amounts are net of income tax, if subject to tax, and after NCI.

Reclassifications out of AOCI Table


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2023		2022
Sempra:
Foreign currency translation adjustments	$	—	$	1	Operation and Maintenance

Financial instruments:

Interest rate instruments	$	(14)	$	13	Equity Earnings(1)
Foreign exchange instruments	—		(1)		Revenues: Energy-Related Businesses
	1		1		Other Income (Expense), Net
Foreign exchange instruments	1		—		Equity Earnings
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense

Total, before income tax	(13)		12
	—		(4)		Income Tax Expense
Total, net of income tax	(13)		8
	9		3		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(4)	$	11

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	2	Other Income (Expense), Net
Amortization of prior service cost	—		1		Other Income (Expense), Net

Total, before income tax	1		3
	—		(1)		Income Tax Expense
Total, net of income tax	$	1	$	2

Total reclassifications for the period, net of income tax and after NCI	$	(3)	$	14





SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense









Total reclassifications for the period, net of income tax	$	1	$	1

(1) Equity earnings at our foreign equity method investees are recognized after tax.

(2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above).


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2023		2022
Sempra:
Foreign currency translation adjustments	$	—	$	1	Operation and Maintenance

Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	(21)		27		Equity Earnings(1)
Foreign exchange instruments	—		(2)		Revenues: Energy-Related Businesses
	2		1		Other Income (Expense), Net
Foreign exchange instruments	2		(1)		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense
	(6)		(6)		Other Income (Expense), Net
Total, before income tax	(24)		17
	3		(5)		Income Tax Expense
Total, net of income tax	(21)		12
	12		3		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(9)	$	15

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	4	Other Income (Expense), Net
Amortization of prior service cost	1		2		Other Income (Expense), Net
Total, before income tax	2		6
	—		(2)		Income Tax Expense
Total, net of income tax	$	2	$	4

Total reclassifications for the period, net of income tax and after NCI	$	(7)	$	20





SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense

Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income (Expense), Net
Amortization of prior service cost	1		—		Other Income (Expense), Net


Total, net of income tax	$	1	$	1

Total reclassifications for the period, net of income tax	$	2	$	2

(1) Equity earnings at our foreign equity method investees are recognized after tax.

(2) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” above).

Ownership Interests Held By Others Table


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	2,424	$	2,060
SI Partners subsidiaries(1)	0.1 - 30.0		0.1 - 16.6		734		61
Total Sempra					$	3,158	$	2,121

(1) SI Partners has subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

Transactions with Affiliates Table

We summarize amounts due from and to unconsolidated affiliates at Sempra, SDG&E and SoCalGas in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	15	$	41
Various affiliates	11		13
Total due from unconsolidated affiliates – current	$	26	$	54

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V. – 5.5% Note due January 9, 2024	$	(5)	$	—
Total due to unconsolidated affiliates – current	$	(5)	$	—

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	—	$	(40)
5.5% Note due January 14, 2025	(23)		(23)
5.5% Note due July 16, 2025	(22)		(21)
5.5% Note due January 14, 2026	(19)		(19)
5.5% Note due July 14, 2026	(11)		(11)
5.5% Note due January 19, 2027	(14)		—
TAG – 5.74% Note due December 17, 2029	(193)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(282)	$	(301)
SDG&E:
Various affiliates	$	1	$	—
Total due from unconsolidated affiliates – current	$	1	$	—

Sempra	$	(29)	$	(49)
SoCalGas	—		(72)
Various affiliates	(14)		(14)
Total due to unconsolidated affiliates – current	$	(43)	$	(135)

Income taxes due (to) from Sempra(2)	$	(32)	$	10
SoCalGas:
SDG&E	$	—	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	1	$	77

Sempra	$	(36)	$	(36)
Total due to unconsolidated affiliates – current	$	(36)	$	(36)

Income taxes due to Sempra(2)	$	(11)	$	(16)

(1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding.

The following table summarizes income statement information from unconsolidated affiliates.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra:
Revenues	$	11	$	15	$	24	$	22

Interest income	—		4		—		14
Interest expense	4		4		8		8
SDG&E:
Revenues	$	6	$	4	$	10	$	8
Cost of sales	27		26		57		50
SoCalGas:
Revenues	$	28	$	23	$	62	$	49
Cost of sales(1)	4		(4)		35		(4)

(1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.

Other Income and Expense Table

Other Income (Expense), Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Sempra:
Allowance for equity funds used during construction	$	37	$	34	$	70	$	69
Investment gains (losses), net(1)	5		(34)		17		(47)
(Losses) gains on interest rate and foreign exchange instruments, net	(1)		(1)		4		5
Foreign currency transaction gains (losses), net(2)	3		(3)		4		(22)
Non-service components of net periodic benefit cost	(26)		(9)		(51)		32
Interest on regulatory balancing accounts, net	19		4		37		5
Sundry, net	(6)		8		(9)		(5)
Total	$	31	$	(1)	$	72	$	37
SDG&E:
Allowance for equity funds used during construction	$	23	$	21	$	46	$	42
Non-service components of net periodic benefit cost	(5)		(2)		(9)		9
Interest on regulatory balancing accounts, net	11		3		21		4
Sundry, net	(7)		—		(8)		1
Total	$	22	$	22	$	50	$	56
SoCalGas:
Allowance for equity funds used during construction	$	14	$	13	$	24	$	26
Non-service components of net periodic benefit cost	(19)		(6)		(38)		26
Interest on regulatory balancing accounts, net	8		1		16		1
Sundry, net	(2)		(4)		(9)		(15)
Total	$	1	$	4	$	(7)	$	38

Income Tax Expense and Effective Income Tax Rates Table

We provide our calculations of ETRs in the following table.


INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2023			2022			2023			2022
Sempra:
Income tax expense	$	175		$	80		$	551		$	414

Income before income taxes and equity earnings	$	523		$	364		$	1,852		$	1,029
Equity earnings, before income tax(1)	153			159			285			302
Pretax income	$	676		$	523		$	2,137		$	1,331

Effective income tax rate	26		%	15		%	26		%	31		%
SDG&E:
Income tax expense	$	4		$	42		$	11		$	106
Income before income taxes	$	188		$	218		$	453		$	516
Effective income tax rate	2		%	19		%	2		%	21		%
SoCalGas:
Income tax (benefit) expense	$	(21)		$	19		$	73		$	103
Income before income taxes	$	135		$	107		$	589		$	525
Effective income tax rate	(16)		%	18		%	12		%	20		%

(1) We discuss how we recognize equity earnings in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	6 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Effective May 12, 2023, our company changed its legal name from Sempra Energy to Sempra. Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities. We have four separate reportable segments, which we discuss in Note 11. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra.
Basis of Presentation	BASIS OF PRESENTATION This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. We have eliminated intercompany accounts and transactions within Sempra’s consolidated financial statements. We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2023 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. All December 31, 2022 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2022 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes. The information contained in this report should be read in conjunction with the Annual Report.
Regulated Operations	Regulated Operations SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity.
Credit Losses	We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in sales-type leases and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 5. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered.
Variable Interest Entity Policy	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess: ▪the purpose and design of the VIE; ▪the nature of the VIE’s risks and the risks we absorb; ▪the power to direct activities that most significantly impact the economic performance of the VIE; and ▪the obligation to absorb losses or the right to receive benefits that could be significant to the VIE. 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.
Earnings Per Share Policy	Basic EPS is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect.
Interim period effective tax rate policy	Sempra, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted ETR anticipated for the full year. Unusual and infrequent items and items that cannot be reliably estimated are recorded in the interim period in which they occur, which can result in variability in the ETR.
Flow-through rate-making treatment tax policy	For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment: ▪repairs expenditures related to a certain portion of utility plant fixed assets ▪the equity portion of AFUDC, which is non-taxable ▪a portion of the cost of removal of utility plant assets ▪utility self-developed software expenditures ▪depreciation on a certain portion of utility plant assets ▪state income taxes AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment. Under the IRA, beginning in 2023, the scope of projects eligible for investment tax credits was expanded to include standalone energy storage projects. The IRA also provided an election that prospectively permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset. Under this election, SDG&E recorded a regulatory liability to offset these investment tax credits, which reduced SDG&E’s and Sempra’s ETR in 2023. On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the three months and six months ended June 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. SoCalGas recorded an associated regulatory liability for the portion that will benefit customers in the future. We are assessing the potential future impacts of this Revenue Procedure.In the six months ended June 30, 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.
Derivative Financial Instruments	HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk of variability of future cash flows of a given revenue or expense item, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power. ▪SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. ▪Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations. ▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other derivatives to hedge exposures such as GHG allowances. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap. As we discuss in Note 6, a minimum of 60% of the projected amount of term loans outstanding is required to be hedged under the Port Arthur LNG term loan facility agreement. In March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps with 17 counterparties to hedge the variability in cash flows related to the SOFR-based component of interest payments on forecasted loans outstanding under the agreement. The notional amounts of the interest rate swaps generally increase in proportion to the forecasted borrowings up to a maximum amount of $4.2 billion prior to the maturity of the term loans on March 20, 2030. Under the interest rate swaps, which are designated as cash flow hedges, Port Arthur LNG receives interest at Term SOFR and pays interest at a fixed rate of 3.23% based on amortizing notional amounts maturing in 2048. FOREIGN CURRENCY DERIVATIVES We may utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican fixed interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. CREDIT RISK RELATED CONTINGENT FEATURES For Sempra, SDG&E and SoCalGas, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. 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 Measurement Policy	We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2022. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following: ▪Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪For commodity contracts, interest rate instruments and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” ▪Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). ▪As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra Infrastructure.” 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 yearWe summarize CRR volumes in Note 7.Realized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings.Fair Value of Financial InstrumentsThe fair values of certain of our financial instruments (cash, accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts.
Gains and Losses on NDTs	Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Legal Proceedings	LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.
Segment Information	We have four separately managed reportable segments, as follows: ▪SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electricity transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, L.L.C., a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, the FERC. The cost of common services shared by the business segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

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

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

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

INVESTMENTS IN UNCONSOLIDATED ENTITIES

6 Months Ended

Jun. 30, 2023

Investments [Abstract]

INVESTMENTS IN UNCONSOLIDATED ENTITIES

We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Condensed Consolidated Statements of Operations. See Note 11 for information on equity earnings and losses, both before and net of income tax, by segment. See Note 1 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.

We provide additional information concerning our equity method investments in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

SEMPRA TEXAS UTILITIES

Oncor Holdings

We account for our 100% equity ownership interest in Oncor Holdings, which owns an 80.25% interest in Oncor, as an equity method investment. Due to the ring-fence measures, governance mechanisms and commitments in effect, we do not have the power to direct the significant activities of Oncor Holdings and Oncor. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information related to the restrictions on our ability to direct the significant activities of Oncor Holdings and Oncor.

In the six months ended June 30, 2023 and 2022, Sempra contributed $178 million and $171 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $204 million and $170 million, respectively, to Sempra.

We provide summarized income statement information for Oncor Holdings in the following table.


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Operating revenues	$	1,343	$	1,293	$	2,635	$	2,542
Operating expenses	(976)		(908)		(2,000)		(1,805)
Income from operations	367		385		635		737
Interest expense	(133)		(108)		(256)		(216)
Income tax expense	(43)		(52)		(67)		(94)
Net income	197		226		296		417
Noncontrolling interest held by Texas Transmission Investment LLC	(40)		(46)		(60)		(84)
Earnings attributable to Sempra(1)	157		180		236		333

SEMPRA INFRASTRUCTURE

Cameron LNG JV

In the six months ended June 30, 2023 and 2022, Sempra Infrastructure contributed $6 million and $10 million, respectively, to Cameron LNG JV, and Cameron LNG JV distributed $198 million and $233 million, respectively, to Sempra Infrastructure.

Sempra Promissory Note for SDSRA Distribution

Cameron LNG JV’s debt agreements require Cameron LNG JV to maintain the SDSRA, which is an additional reserve account beyond the Senior Debt Service Accrual Account, where funds accumulate from operations to satisfy senior debt obligations due and payable on the next payment date. Both accounts can be funded with cash or authorized investments. In June 2021, Sempra Infrastructure received a distribution of $165 million based on its proportionate share of the SDSRA, for which Sempra provided a promissory note and letters of credit to secure a proportionate share of Cameron LNG JV’s obligation to fund the SDSRA. Sempra’s maximum exposure to loss is replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $20 million at June 30, 2023, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra Infrastructure’s investment in Cameron LNG JV. The guarantee will terminate upon full repayment of Cameron LNG JV’s debt, scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA.

Sempra Support Agreement for CFIN

In July 2020, CFIN entered into a financing arrangement with Cameron LNG JV’s four project owners and received aggregate proceeds of $1.5 billion from two project owners and from external lenders on behalf of the other two project owners (collectively, the affiliate loans), based on their proportionate ownership interest in Cameron LNG JV. CFIN used the proceeds from the affiliate loans to provide a loan to Cameron LNG JV. The affiliate loans mature in 2039. Principal and interest will be paid from Cameron LNG JV’s project cash flows from its three-train natural gas liquefaction facility. Cameron LNG JV used the proceeds from its loan to return equity to its project owners. Sempra used its $753 million share of the proceeds for working capital and other general corporate purposes, including the repayment of indebtedness.

Sempra Infrastructure’s $753 million proportionate share of the affiliate loans, based on SI Partners’ 50.2% ownership interest in Cameron LNG JV, was funded by external lenders comprised of a syndicate of eight banks (the bank debt) to whom Sempra has provided a guarantee pursuant to a Support Agreement under which:

▪Sempra has severally guaranteed repayment of the bank debt plus accrued and unpaid interest if CFIN fails to pay the external lenders;

▪the external lenders may exercise an option to put the bank debt to Sempra Infrastructure upon the occurrence of certain events, including a failure by CFIN to meet its payment obligations under the bank debt;

▪the external lenders will put some or all of the bank debt to Sempra Infrastructure on the fifth, tenth, or fifteenth anniversary date of the affiliate loans, except the portion of the debt owed to any external lender that has elected not to participate in the put option six months prior to the respective anniversary date;

▪Sempra Infrastructure also has a right to call the bank debt back from, or to refinance the bank debt with, the external lenders at any time; and

▪the Support Agreement will terminate upon full repayment of the bank debt, including repayment following an event in which the bank debt is put to Sempra Infrastructure.

In exchange for this guarantee, the external lenders pay a guarantee fee that is based on the credit rating of Sempra’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra Infrastructure recognizes as interest income as earned. Sempra’s maximum exposure to loss is the bank debt plus any accrued and unpaid interest and related fees, subject to a liability cap of 130% of the bank debt, or $979 million. We measure the Support Agreement at fair value, net of related guarantee fees, on a recurring basis (see Note 8). At June 30, 2023, the fair value of the Support Agreement was $23 million, of which $7 million is included in Other Current Assets and $16 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

TAG

In the six months ended June 30, 2023 and 2022, TAG distributed $36 million and $32 million, respectively, to Sempra Infrastructure.

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

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

SEGMENT INFORMATION - NARRATIVE (Details)	6 Months Ended
SEGMENT INFORMATION - NARRATIVE (Details)	Jun. 30, 2023 segment
Segment Reporting Information [Line Items]
Number of reportable segments	4
Oncor Electric Delivery Company LLC Additional Acquisition \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	80.25%
Sharyland Holdings, LP \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	50.00%

REGULATORY MATTERS

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]

REGULATORY MATTERS


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	8	$	(110)
Deferred income taxes recoverable in rates	429		296
Pension and PBOP plan obligations	3		11
Removal obligations	(2,371)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	121		123
Regulatory balancing accounts(1)(2):
Commodity – electric	181		220
Gas transportation	7		60
Safety and reliability	158		107
Public purpose programs	(109)		(69)
Wildfire mitigation plan	519		375
Liability insurance premium	102		99
Other balancing accounts	(342)		(50)
Other regulatory assets, net(2)	153		137
Total SDG&E	(1,035)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	241		161
Pension and PBOP plan obligations	(232)		(170)
Employee benefit costs	24		24
Removal obligations	(591)		(616)
Environmental costs	37		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(362)		(257)
Safety and reliability	644		575
Public purpose programs	(152)		(158)
Liability insurance premium	22		23
Other balancing accounts	288		115
Other regulatory assets, net(2)	280		223
Total SoCalGas	199		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	5		—
Total Sempra Infrastructure	83		78
Total Sempra	$	(753)	$	(906)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

SEMPRA CALIFORNIA

CPUC GRC

CPUC Cost of Capital


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base(1)			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.05	%	1.83	%	Long-Term Debt	45.60	%	4.07	%	1.86	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		9.95		5.17		Common Equity	52.00		9.80		5.10
100.00	%			7.18	%		100.00	%			7.10	%

(1) Total weighted return on rate base does not sum due to rounding differences.

SDG&E

FERC Rate Matters

SAN ONOFRE NUCLEAR GENERATING STATION

NUCLEAR DECOMMISSIONING AND FUNDING

on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal. SDG&E is responsible for approximately 20% of the total decommissioning cost.


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	40	$	1	$	(2)	$	39
Municipal bonds(2)	277		1		(12)		266
Other securities(3)	234		—		(16)		218
Total debt securities	551		2		(30)		523
Equity securities	104		222		(4)		322
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(6)		—		—		(6)
Total	$	673	$	224	$	(34)	$	863

	December 31, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	40	$	1	$	(1)	$	40
Municipal bonds	283		1		(14)		270
Other securities	248		—		(21)		227
Total debt securities	571		2		(36)		537
Equity securities	111		194		(8)		297
Short-term investments, primarily cash equivalents	11		—		—		11
Receivables (payables), net	(4)		—		—		(4)
Total	$	689	$	196	$	(44)	$	841

(1) Maturity dates are 2023-2053.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales.


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Proceeds from sales	$	138	$	155	$	294	$	397
Gross realized gains	6		3		8		14
Gross realized losses	(3)		(7)		(6)		(11)

ASSET RETIREMENT OBLIGATION

REGULATORY MATTERS - GENERAL RATE CASE (Details) - 2024 GRC - 2024 Requirement - General Rate Case $ in Billions	1 Months Ended
	May 31, 2022 USD ($)
San Diego Gas and Electric Company
General Rate Case [Line Items]
Requested revenue requirements	$ 3.0
San Diego Gas and Electric Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases	8.00%
San Diego Gas and Electric Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases	11.00%
Southern California Gas Company
General Rate Case [Line Items]
Requested revenue requirements	$ 4.4
Southern California Gas Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases	6.00%
Southern California Gas Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases	8.00%

COVER - shares	6 Months Ended
COVER - shares	Jun. 30, 2023	Jul. 31, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		314,653,565
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company
Document Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8330 Century Park Court
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92123
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000086521
Southern California Gas Company
Document Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West 5th Street
Entity Address, City or Town	Los Angeles
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90013
City Area Code	(213)
Local Phone Number	244-1200
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000092108
Common stock
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
5.75% Junior Subordinated Notes Due 2079
Document Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE

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

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

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - San Diego Gas and Electric Company - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Jointly Owned Nuclear Power Plant
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20.00%
Anticipated term of dismantlement work	10 years
Percent of dismantlement work expense (as a percent)	20.00%
ARO related to decommissioning costs	$ 523
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 81

SUBSEQUENT EVENT

6 Months Ended

Jun. 30, 2023

Subsequent Events [Abstract]

SUBSEQUENT EVENT

SEMPRA COMMON STOCK SPLIT IN THE FORM OF A STOCK DIVIDEND

On August 2, 2023, Sempra’s board of directors declared a two-for-one split of Sempra’s common stock in the form of a 100% stock dividend for shareholders of record at the close of business on August 14, 2023. Each shareholder of record will receive one additional share of Sempra common stock for every then-held share of Sempra common stock, to be distributed after the close of trading on August 21, 2023. We expect Sempra’s common stock will begin trading on a post-split basis effective August 22, 2023. Sempra’s common stock will continue to have no par value with 1,125,000,000 authorized shares.

The following represents the unaudited pro forma effect of the two-for-one stock split as if it had been effective for all periods presented:


PRO FORMA EARNINGS PER COMMON SHARE COMPUTATIONS ON A POST-SPLIT BASIS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	603	$	559	$	1,572	$	1,171

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	630,014		629,691		629,926		631,190
Dilutive effect of stock options and RSUs	2,107		2,044		2,259		2,104
Weighted-average common shares outstanding for diluted EPS	632,121		631,735		632,185		633,294

EPS:
Basic	$	0.96	$	0.89	$	2.50	$	1.86
Diluted	$	0.95	$	0.89	$	2.49	$	1.85

Upon the distribution date for the stock dividend, all historical shares and per share information related to issued and outstanding common stock and outstanding equity awards exercisable into common stock will be retroactively adjusted to reflect the stock split in future financial statements.

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		6 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) projectOwner bank	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 402	$ 403
Oncor Holdings \| Oncor Electric Delivery Company LLC.
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			80.25%
Sempra Texas Intermediate Holding Company LLC \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			100.00%
Sempra Texas Utilities \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Investments made during period			$ 178	171
Proceeds from distributions received			$ 204	170
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity (in percentage)			50.20%
Sempra Infrastructure \| TAG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 36	32
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			23
Sempra Infrastructure \| Other current assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			7
Sempra Infrastructure \| Other long-term assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			16
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Investments made during period			6	10
Proceeds from distributions received			$ 198	$ 233
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of project owners \| projectOwner		4
Proceeds from related party debt		$ 1,500
Number of project owners sending direct proceeds \| projectOwner		2
Number of project owners sending proceeds from external lenders \| projectOwner		2
Liability cap (as a percent)			130.00%
Liability cap, amount			$ 979
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related party debt		$ 753
Return on investments		$ 753
Number of banks \| bank		8
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received	$ 165
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Deferred Credits and Other
Schedule of Equity Method Investments [Line Items]
Senior note, liability	$ 22
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Other current liabilities
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 20

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023 USD ($) $ / MWh	Jun. 30, 2022 USD ($) $ / MWh	Jun. 30, 2023 USD ($) $ / MWh	Jun. 30, 2022 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 30	$ 58	$ 35	$ 54
Realized and unrealized losses	(4)	(30)	(8)	(23)
Allocated transmission instruments	(2)	(6)	(2)	(6)
Settlements	(4)	11	(5)	8
Ending balance	20	33	20	33
Change in unrealized losses relating to instruments still held at June 30	(7)	(23)	(9)	(18)
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	24	12	17	7
Realized and unrealized gains	1	6	10	14
Settlements	(2)	(2)	(4)	(5)
Ending balance	23	16	23	16
Change in unrealized gains (losses) relating to instruments still held at the end of the period	1	5	9	13
Sempra Infrastructure \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Sempra Infrastructure \| Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	16		16
San Diego Gas and Electric Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	30	58	35	54
Realized and unrealized losses	(4)	(30)	(8)	(23)
Allocated transmission instruments	(2)	(6)	(2)	(6)
Settlements	(4)	11	(5)	8
Ending balance	20	33	20	33
Change in unrealized losses relating to instruments still held at June 30	$ (7)	$ (23)	$ (9)	$ (18)
Level 3 \| San Diego Gas and Electric Company \| Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(3.09)	(3.67)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	22.75	25.25	22.75	25.25
Level 3 \| San Diego Gas and Electric Company \| Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			10.71	6.96
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	117.50	125.00	117.50	125.00
Level 3 \| San Diego Gas and Electric Company \| Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(0.56)	(0.70)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh	74.02	66.36	74.02	66.36

SUBSEQUENT EVENT - Narrative (Details)	Aug. 02, 2023 shares	Jun. 30, 2023 shares	May 12, 2023 shares	May 11, 2023 shares	Dec. 31, 2022 shares
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Common stock, shares authorized (in shares)		1,125,000,000	1,125,000,000	750,000,000	1,125,000,000
Subsequent Event
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Stock split, conversion ratio	2
Stock dividend (in percent)	100.00%
Common stock, shares authorized (in shares)	1,125,000,000

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

Jun. 30, 2022

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Restricted cash, noncurrent

$ 1,077

$ 370

^[1]

Restricted cash, current

^[1]

^[1]

Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows

$ 1,242

$ 462

$ 2,093

$ 581

[1]	Derived from audited financial statements.

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

CONDENSED BALANCE SHEETS - SoCalGas - USD ($)
$ in Millions

Jun. 30, 2023

Dec. 31, 2022

$ 1,077

$ 370

^[1]

1,970

2,635

^[1]

489

685

^[1]

^[1]

383

403

^[1]

105

351

^[1]

143

141

^[1]

^[1]

4,847

5,912

^[1]

3,227

2,588

^[1]

1,045

796

^[1]

722

655

^[1]

1,549

1,382

^[1]

26,402

24,880

^[1]

68,270

63,893

^[1]

(16,792)

(16,111)

^[1]

51,478

47,782

^[1]

82,727

78,574

^[1]

2,512

3,352

^[1]

Accounts payable – trade

1,790

1,994

^[1]

Accounts payable – other

234

275

^[1]

364

484

^[1]

Current portion of long-term debt and finance leases

650

504

^[1]

924

1,019

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

143

141

^[1]

8,451

9,899

^[1]

27,521

24,548

^[1]

3,435

3,341

^[1]

Pension and other postretirement benefit plan obligations, net of plan assets

800

565

^[1]

346

410

^[1]

5,064

4,591

^[1]

3,536

3,546

^[1]

2,278

2,117

^[1]

15,741

14,871

^[1]

^[1]

Equity:

12,044

12,160

^[1]

15,024

14,201

^[1]

(121)

(135)

^[1]

27,836

27,115

^[1]

82,727

78,574

^[1]

Related Party

^[1]

Nonrelated Party

1,052

1,380

^[1]

^[1]

856

1,295

^[1]

293

^[1]

^[1]

180

159

^[1]

104

^[1]

113

111

^[1]

^[1]

1,338

2,129

^[1]

1,585

1,291

^[1]

729

551

^[1]

^[1]

605

583

^[1]

2,954

2,467

^[1]

25,872

25,058

^[1]

(7,573)

(7,308)

^[1]

18,299

17,750

^[1]

22,591

22,346

^[1]

238

900

^[1]

Accounts payable – trade

509

953

^[1]

Accounts payable – other

161

176

^[1]

170

209

^[1]

Current portion of long-term debt and finance leases

418

394

^[1]

318

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

113

111

^[1]

^[1]

2,171

3,723

^[1]

6,790

5,780

^[1]

1,029

1,043

^[1]

Pension and other postretirement benefit plan obligations, net of plan assets

630

443

^[1]

225

277

^[1]

1,466

1,306

^[1]

2,672

2,675

^[1]

393

401

^[1]

6,415

6,145

^[1]

^[1]

Equity:

Preferred stock

^[1]

2,316

^[1]

4,899

4,384

^[1]

(22)

(24)

^[1]

7,215

6,698

^[1]

Southern California Gas Company | Related Party

22,591

22,346

^[1]

Southern California Gas Company | Nonrelated Party

^[1]