0001032208-23-000027 | 10-Q | XBRL Viewer

$ 534

$ 370

Restricted cash

2,581

2,635

Due from unconsolidated affiliates

498

685

Income taxes receivable

113

315

403

Prepaid expenses

255

268

Fixed-price contracts and other derivatives

115

351

460

803

143

141

5,204

5,912

Restricted cash

2,935

2,588

Nuclear decommissioning trusts

907

796

864

841

Dedicated assets in support of certain benefit plans

511

505

148

135

Investment in Oncor Holdings

639

655

13,735

13,665

Other investments

2,001

2,012

Goodwill

1,602

Other intangible assets

337

344

Wildfire fund

295

303

1,482

1,382

25,540

24,880

66,284

63,893

(16,479)

(16,111)

49,805

47,782

80,549

78,574

3,037

3,352

Accounts payable – trade

2,122

1,994

Accounts payable – other

283

275

Dividends and interest payable

667

621

344

484

Current portion of long-term debt and finance leases

427

504

1,220

1,019

Reserve for Aliso Canyon costs

129

143

141

1,217

1,380

9,630

9,899

25,206

24,548

278

301

3,408

3,341

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

650

565

378

410

4,938

4,591

3,564

3,546

2,252

2,117

15,468

14,871

Equity:

12,164

12,160

14,796

14,201

(182)

(135)

Preferred stock of subsidiary

27,667

27,115

2,558

2,121

Total equity

30,245

29,256

Beginning Balance at Dec. 31, 2021

80,549

78,574

Series C Preferred Stock

Equity:

Preferred stock

$ 889

[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Mar. 31, 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)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,172	$ 657
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	539	493
Deferred income taxes and investment tax credits	253	347
Equity earnings	(219)	(326)
Foreign currency transaction (gains) losses, net	(1)	19
Share-based compensation expense	17	17
Fixed-price contracts and other derivatives	(374)	105
Other	142	50
Net change in working capital components	451	326
Distributions from investments	199	204
Changes in other noncurrent assets and liabilities, net	(199)	(285)
Net cash provided by operating activities	1,980	1,607
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,830)	(1,204)
Expenditures for investments	(85)	(85)
Purchases of nuclear decommissioning and other trust assets	(181)	(242)
Proceeds from sales of nuclear decommissioning and other trust assets	199	242
Other	2	(1)
Net cash used in investing activities	(1,895)	(1,290)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(360)	(349)
Issuances of common stock	0	3
Repurchases of common stock	(31)	(226)
Issuances of debt (maturities greater than 90 days)	1,986	4,023
Payments on debt (maturities greater than 90 days) and finance leases	(1,803)	(1,048)
Increase (decrease) in short-term debt, net	168	(720)
Advances from unconsolidated affiliates	14	18
Proceeds from sales of noncontrolling interests	265	13
Distributions to noncontrolling interests	(43)	(53)
Contributions from noncontrolling interests	97	6
Settlement of cross-currency swaps	(99)	0
Other	(43)	(29)
Net cash provided by financing activities	151	1,638
Effect of exchange rate changes on cash, cash equivalents and restricted cash	5	0
Increase in cash, cash equivalents and restricted cash	241	1,955
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, March 31	703	2,536
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	305	233
Income tax payments, net of refunds	50	80
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,171	468
Increase in finance lease obligations for investment in PP&E	17	13
Increase in ARO for investment in PP&E	0	23
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	$ 374	$ 362

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 Energy 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]

Total other comprehensive (loss) income

657

623

110

Share-based compensation expense

Dividends declared:

Preferred dividends

$ (11)

Common stock dividends declared

(362)

Issuances of common stock

Repurchases of common stock

(226)

Noncontrolling interest activities:

Contributions

Distributions

(53)

Ending balance at Mar. 31, 2022

27,560

889

11,656

13,798

(229)

26,114

1,446

Beginning Balance at Dec. 31, 2022

29,256

^[1]

889

12,160

14,201

(135)

27,115

2,141

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

Total other comprehensive (loss) income

1,172

980

192

(93)

(47)

(46)

Share-based compensation expense

Dividends declared:

Preferred dividends

$ (11)

Common stock dividends declared

(374)

Repurchases of common stock

(31)

Noncontrolling interest activities:

Contributions

Distributions

(43)

Sale

255

237

Ending balance at Mar. 31, 2023

$ 30,245

$ 889

$ 12,164

$ 14,796

$ (182)

$ 27,667

$ 2,578

[1]	Derived from audited financial statements.

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Dividends declared per share of common stock (in dollars per share)	$ 1.19	$ 1.15
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19

CONDENSED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
REVENUES
Electric	$ 1,027	$ 1,117
Natural gas	4,412	2,320
Operating expenses:
Other Income, Net	41	38
Interest income	24	25
Interest expense	(366)	(243)
Income before income taxes and equity earnings	1,329	665
Income tax expense	(376)	(334)
Net income	1,172	657
Earnings attributable to common shares	969	612
San Diego Gas and Electric Company
REVENUES
Electric	1,031	1,120
Natural gas	622	325
Operating revenues	1,653	1,445
Operating expenses:
Cost of electric fuel and purchased power	135	221
Cost of natural gas	379	126
Operation and maintenance	427	397
Depreciation and amortization	262	239
Franchise fees and other taxes	96	92
Total operating expenses	1,299	1,075
Operating income	354	370
Other Income, Net	28	34
Interest income	1	0
Interest expense	(118)	(106)
Income before income taxes and equity earnings	265	298
Income tax expense	(7)	(64)
Net income	258	234
Earnings attributable to common shares	$ 258	$ 234

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 1,172	$ 657
Pretax amount
Net income	1,356	957
Income tax (expense) benefit
Net income	(376)	(334)
Net-of-tax amount
Net income	980	623
San Diego Gas and Electric Company
Net income	258	234
San Diego Gas and Electric Company \| Pretax amount
Net income	265	298
Comprehensive income	265	298
San Diego Gas and Electric Company \| Income tax (expense) benefit
Net income	(7)	(64)
Comprehensive income	(7)	(64)
San Diego Gas and Electric Company \| Net-of-tax amount
Net income	258	234
Comprehensive income	$ 258	$ 234

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

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

Mar. 31, 2023

Dec. 31, 2022

^[1]

$ 534

$ 370

2,581

2,635

498

685

315

403

Prepaid expenses

255

268

Fixed-price contracts and other derivatives

115

351

460

803

143

141

5,204

5,912

2,935

2,588

Nuclear decommissioning trusts

907

796

864

841

639

655

Wildfire fund

295

303

1,482

1,382

25,540

24,880

66,284

63,893

(16,479)

(16,111)

49,805

47,782

80,549

78,574

3,037

3,352

344

484

Current portion of long-term debt and finance leases

427

504

1,220

1,019

143

141

1,217

1,380

9,630

9,899

25,206

24,548

3,408

3,341

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

650

565

378

410

4,938

4,591

3,564

3,546

2,252

2,117

15,468

14,871

Equity:

12,164

12,160

14,796

14,201

(182)

(135)

27,667

27,115

80,549

78,574

336

859

799

115

110

143

134

Prepaid expenses

146

179

Fixed-price contracts and other derivatives

247

101

113

1,799

1,630

1,404

1,219

Nuclear decommissioning trusts

216

196

864

841

273

281

Wildfire fund

295

303

145

146

3,197

2,986

29,126

28,574

(6,934)

(6,768)

22,192

21,806

27,188

26,422

205

Accounts payable

578

744

143

135

Interest payable

140

Accrued franchise fees

120

Current portion of long-term debt and finance leases

110

891

489

106

264

193

2,314

2,319

8,872

8,497

2,366

2,298

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

2,567

2,540

779

789

829

789

6,677

6,539

Equity:

Preferred stock

1,660

7,672

7,414

(7)

9,325

9,067

Beginning Balance at Dec. 31, 2021

$ 27,188

$ 26,422

[1]	Derived from audited financial statements.

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Mar. 31, 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)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
San Diego Gas and Electric Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	117,000,000	117,000,000

CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,172	$ 657
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	539	493
Deferred income taxes and investment tax credits	253	347
Other	142	50
Net change in working capital components	451	326
Changes in other noncurrent assets and liabilities, net	(199)	(285)
Net cash provided by operating activities	1,980	1,607
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,830)	(1,204)
Purchases of nuclear decommissioning and other trust assets	(181)	(242)
Proceeds from sales of nuclear decommissioning and other trust assets	199	242
Net cash used in investing activities	(1,895)	(1,290)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	1,986	4,023
Payments on debt (maturities greater than 90 days) and finance leases	(1,803)	(1,048)
Increase (decrease) in short-term debt, net	168	(720)
Net cash provided by financing activities	151	1,638
Increase in cash, cash equivalents and restricted cash	241	1,955
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, March 31	703	2,536
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	305	233
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,171	468
Increase in finance lease obligations for investment in PP&E	17	13
San Diego Gas and Electric Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	258	234
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	262	239
Deferred income taxes and investment tax credits	(11)	4
Other	26	11
Net change in working capital components	(51)	272
Changes in other noncurrent assets and liabilities, net	(112)	(90)
Net cash provided by operating activities	372	670
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(624)	(552)
Purchases of nuclear decommissioning and other trust assets	(145)	(242)
Proceeds from sales of nuclear decommissioning and other trust assets	156	242
Net cash used in investing activities	(613)	(552)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	792	1,195
Payments on debt (maturities greater than 90 days) and finance leases	(9)	(400)
Increase (decrease) in short-term debt, net	(205)	(401)
Debt issuance costs	(8)	(9)
Net cash provided by financing activities	570	385
Increase in cash, cash equivalents and restricted cash	329	503
Cash, cash equivalents and restricted cash, January 1	7	25
Cash, cash equivalents and restricted cash, March 31	336	528
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	94	81
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	186	164
Increase in finance lease obligations for investment in PP&E	$ 2	$ 5

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E - USD ($)
$ in Millions

Total

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

Sempra Energy shareholders' equity

San Diego Gas and Electric Company

Common stock

San Diego Gas and Electric Company

Retained earnings

San Diego Gas and Electric Company

Accumulated other comprehensive income (loss)

San Diego Gas and Electric Company

Sempra Energy shareholders' equity

$ 27,419

$ 11,862

$ 13,548

$ (318)

$ 25,981

$ 1,660

$ 6,599

$ (10)

$ 8,249

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

Ending balance at Mar. 31, 2022

657

623

$ 234

234

27,560

11,656

13,798

(229)

26,114

1,660

6,833

(10)

8,483

Beginning Balance at Dec. 31, 2022

29,256

^[1]

12,160

14,201

(135)

27,115

1,660

7,414

(7)

9,067

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

Ending balance at Mar. 31, 2023

1,172

980

$ 258

258

$ 30,245

$ 12,164

$ 14,796

$ (182)

$ 27,667

$ 1,660

$ 7,672

$ (7)

$ 9,325

[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.

Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity.

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CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating expenses:
Aliso Canyon litigation and regulatory matters	$ 0	$ 92
Other (expense) income, net	41	38
Interest income	24	25
Interest expense	(366)	(243)
Income before income taxes and equity earnings	1,329	665
Income tax expense	(376)	(334)
Net income	1,172	657
Earnings attributable to common shares	969	612
Southern California Gas Company
REVENUES
Operating revenues	3,794	1,993
Operating expenses:
Cost of natural gas	2,347	677
Operation and maintenance	625	551
Aliso Canyon litigation and regulatory matters	0	92
Depreciation and amortization	206	187
Franchise fees and other taxes	89	62
Total operating expenses	3,267	1,569
Operating income	527	424
Other (expense) income, net	(8)	34
Interest income	4	0
Interest expense	(69)	(40)
Income before income taxes and equity earnings	454	418
Income tax expense	(94)	(84)
Net income	360	334
Earnings attributable to common shares	$ 360	$ 334

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SoCalGas - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 1,172	$ 657
Other comprehensive income (loss):
Pension and other postretirement benefits	(12)	8
Total other comprehensive (loss) income	(93)	110
Pretax amount
Net income	1,356	957
Other comprehensive income (loss):
Pension and other postretirement benefits	(12)	9
Total other comprehensive (loss) income	(63)	114
Income tax (expense) benefit
Net income	(376)	(334)
Other comprehensive income (loss):
Pension and other postretirement benefits	0	(1)
Total other comprehensive (loss) income	16	(25)
Net-of-tax amount
Net income	980	623
Other comprehensive income (loss):
Pension and other postretirement benefits	(12)	8
Total other comprehensive (loss) income	(47)	89
Southern California Gas Company
Net income	360	334
Other comprehensive income (loss):
Total other comprehensive (loss) income	1	1
Southern California Gas Company \| Pretax amount
Net income	454	418
Other comprehensive income (loss):
Pension and other postretirement benefits	1	1
Total other comprehensive (loss) income	1	1
Comprehensive income	455	419
Southern California Gas Company \| Income tax (expense) benefit
Net income	(94)	(84)
Other comprehensive income (loss):
Pension and other postretirement benefits	0	0
Total other comprehensive (loss) income	0	0
Comprehensive income	(94)	(84)
Southern California Gas Company \| Net-of-tax amount
Net income	360	334
Other comprehensive income (loss):
Pension and other postretirement benefits	1	1
Total other comprehensive (loss) income	1	1
Comprehensive income	$ 361	$ 335

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

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

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

Mar. 31, 2023

Dec. 31, 2022

^[1]

$ 534

$ 370

2,581

2,635

Due from unconsolidated affiliates

498

685

315

403

115

351

143

141

5,204

5,912

2,935

2,588

907

796

639

655

1,482

1,382

25,540

24,880

66,284

63,893

(16,479)

(16,111)

49,805

47,782

80,549

78,574

3,037

3,352

Accounts payable – trade

2,122

1,994

Accounts payable – other

283

275

344

484

Current portion of long-term debt and finance leases

427

504

1,220

1,019

Reserve for Aliso Canyon costs

129

143

141

1,217

1,380

9,630

9,899

25,206

24,548

3,408

3,341

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

650

565

378

410

4,938

4,591

3,564

3,546

2,252

2,117

15,468

14,871

Equity:

12,164

12,160

14,796

14,201

(182)

(135)

27,667

27,115

80,549

78,574

1,422

1,295

Due from unconsolidated affiliates

132

293

130

159

104

113

111

2,033

2,129

1,453

1,291

631

551

596

583

2,718

2,467

25,463

25,058

(7,438)

(7,308)

18,025

17,750

22,776

22,346

1,023

900

Accounts payable – trade

677

953

Accounts payable – other

211

176

157

209

Current portion of long-term debt and finance leases

376

394

318

Reserve for Aliso Canyon costs

129

113

111

466

429

3,573

3,723

5,792

5,780

1,042

1,043

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

504

443

251

277

1,440

1,306

2,701

2,675

414

401

6,352

6,145

Equity:

Preferred stock

2,316

4,744

4,384

(23)

(24)

7,059

6,698

Beginning Balance at Dec. 31, 2021

$ 22,776

$ 22,346

[1]	Derived from audited financial statements.

CONDENSED BALANCE SHEETS - SoCalGas (Parentheticals) - shares	Mar. 31, 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)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	315,000,000	314,000,000
Southern California Gas Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	1,000,000	1,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,000,000	91,000,000

CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,172	$ 657
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	539	493
Deferred income taxes and investment tax credits	253	347
Other	142	50
Net change in working capital components	451	326
Changes in other noncurrent assets and liabilities, net	(199)	(285)
Net cash provided by operating activities	1,980	1,607
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,830)	(1,204)
Net cash used in investing activities	(1,895)	(1,290)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	1,986	4,023
Increase (decrease) in short-term debt, net	168	(720)
Net cash provided by financing activities	151	1,638
Increase in cash, cash equivalents and restricted cash	241	1,955
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, March 31	703	2,536
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	305	233
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,171	468
Increase in finance lease obligations for investment in PP&E	17	13
Increase in ARO for investment in PP&E	0	23
Southern California Gas Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	360	334
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	206	187
Deferred income taxes and investment tax credits	86	84
Other	77	24
Net change in working capital components	(244)	323
Changes in other noncurrent assets and liabilities, net	(159)	(211)
Net cash provided by operating activities	326	741
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(458)	(468)
Net cash used in investing activities	(458)	(468)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	0	697
Payments on finance leases	(5)	(3)
Increase (decrease) in short-term debt, net	123	(385)
Debt issuance costs	0	(6)
Net cash provided by financing activities	118	303
Increase in cash, cash equivalents and restricted cash	(14)	576
Cash, cash equivalents and restricted cash, January 1	21	37
Cash, cash equivalents and restricted cash, March 31	7	613
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	65	43
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	219	185
Increase in finance lease obligations for investment in PP&E	15	8
Increase in ARO for investment in PP&E	$ 0	$ 22

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]

Other comprehensive (loss) income

657

623

334

110

Ending balance at Mar. 31, 2022

27,560

889

11,656

13,798

(229)

5,777

1,666

4,119

(30)

Beginning Balance at Dec. 31, 2022

29,256

^[1]

889

12,160

14,201

(135)

6,698

2,316

4,384

(24)

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

Other comprehensive (loss) income

1,172

980

360

(93)

(47)

Ending balance at Mar. 31, 2023

$ 30,245

$ 889

$ 12,164

$ 14,796

$ (182)

$ 7,059

$ 22

$ 2,316

$ 4,744

$ (23)

[1]	Derived from audited financial statements.

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

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Southern California Gas Company
Dividends declared per share of preferred stock (in dollars per share)	$ 0.38	$ 0.38

GENERAL INFORMATION AND OTHER FINANCIAL DATA

3 Months Ended

Mar. 31, 2023

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, 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 the consolidated financial statements of each reporting entity.

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 March 31, 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 Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects; 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)
	March 31, 2023		December 31, 2022
Cash and cash equivalents	$	534	$	370
Restricted cash, current	85		40
Restricted cash, noncurrent	84		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	703	$	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 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the 2021 California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and 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	117		48
Write-offs	(20)		(19)
Allowances for credit losses at March 31	$	278	$	165
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	38		21
Write-offs	(11)		(9)
Allowances for credit losses at March 31	$	105	$	78
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	77		26
Write-offs	(9)		(10)
Allowances for credit losses at March 31	$	166	$	85

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)
	March 31,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	238	$	140
Accounts receivable – other, net	40		40
Other long-term assets	—		1
Total allowances for credit losses	$	278	$	181
SDG&E:
Accounts receivable – trade, net	$	80	$	52
Accounts receivable – other, net	25		25
Other long-term assets	—		1
Total allowances for credit losses	$	105	$	78
SoCalGas:
Accounts receivable – trade, net	$	151	$	83
Accounts receivable – other, net	15		15
Total allowances for credit losses	$	166	$	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 March 31, 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 March 31, 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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Natural gas	$	41	$	106	$	1	$	1	$	24	$	74
LNG	7		62		—		—		—		—
Materials and supplies	267		235		142		133		106		85
Total	$	315	$	403	$	143	$	134	$	130	$	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 March 31, 2023 and December 31, 2022, Other Long-Term Assets includes $320 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 March 31,
		2023		2022
Sempra		$	73	$	57
SDG&E		31		28
SoCalGas		15		18

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 March 31, 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 $1,188 million and $1,194 million at March 31, 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 $13,735 million and $13,665 million at March 31, 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 $880 million at March 31, 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 $1,199 million and $1,099 million of assets at March 31, 2023 and December 31, 2022, respectively, consisting primarily of PP&E, net, and Accounts Receivable – Other 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 $778 million and $685 million of liabilities at March 31, 2023 and December 31, 2022, respectively, consisting primarily of long-term debt, short-term debt and accounts payable 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 $1,901 million of assets at March 31, 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 $913 million of liabilities at March 31, 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, Net, table below.


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022












Service cost	$	28	$	41	$	4	$	7
Interest cost	40		30		9		7
Expected return on assets	(43)		(46)		(17)		(16)
Amortization of:
Prior service cost (credit)	1		3		(1)		(1)
Actuarial loss (gain)	2		6		(6)		(4)
Net periodic benefit cost (credit)	28		34		(11)		(7)
Regulatory adjustments	29		(27)		11		7
Total expense recognized	$	57	$	7	$	—	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022











Service cost	$	8	$	10	$	1	$	2
Interest cost	10		7		2		1
Expected return on assets	(10)		(11)		(2)		(2)
Amortization of:
Actuarial loss (gain)	1		—		(1)		(1)
Net periodic benefit cost	9		6		—		—
Regulatory adjustments	4		(5)		—		—
Total expense recognized	$	13	$	1	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022












Service cost	$	17	$	28	$	3	$	5
Interest cost	25		20		7		5
Expected return on assets	(29)		(31)		(15)		(13)
Amortization of:
Prior service cost (credit)	1		2		(1)		(1)
Actuarial loss (gain)	—		4		(5)		(3)
Net periodic benefit cost (credit)	14		23		(11)		(7)
Regulatory adjustments	25		(22)		11		7
Total expense recognized	$	39	$	1	$	—	$	—

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 $511 million and $505 million at March 31, 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 March 31,
		2023		2022
Numerator:
Earnings attributable to common shares		$	969	$	612

Denominator:
Weighted-average common shares outstanding for basic EPS(1)		314,919		316,353
Dilutive effect of stock options and RSUs(2)		1,205		1,081
Weighted-average common shares outstanding for diluted EPS		316,124		317,434

EPS:
Basic		$	3.08	$	1.93
Diluted		$	3.07	$	1.93

(1) Includes 360 and 407 fully vested RSUs held in our Deferred Compensation Plan for the three months ended March 31, 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 ended March 31, 2023 and 2022 excludes 180,015 and 337,239 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.

In January 2023, 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, 325,412 performance-based RSUs and 130,319 service-based RSUs.

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, excluding 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 accumulated other comprehensive income (loss)
	Three months ended March 31, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	10		(40)		(13)		(43)
Amounts reclassified from AOCI	—		(5)		1		(4)
Net OCI	10		(45)		(12)		(47)
Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	3		74		6		83
Amounts reclassified from AOCI	—		4		2		6
Net OCI	3		78		8		89
Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
SDG&E:




Balance at December 31, 2022 and March 31, 2023					$	(7)	$	(7)









Balance at December 31, 2021 and March 31, 2022					$	(10)	$	(10)
SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)

Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at March 31, 2023			$	(12)	$	(11)	$	(23)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at March 31, 2022			$	(13)	$	(17)	$	(30)

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


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended March 31,
	2023		2022
Sempra:
Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	(7)		14		Equity Earnings(1)
Foreign exchange instruments	—		(1)		Revenues: Energy-Related Businesses
	1		—		Other Income, Net
Foreign exchange instruments	1		(1)		Equity Earnings(1)

Interest rate and foreign exchange instruments	(6)		(6)		Other Income, Net
Total, before income tax	(11)		5
	3		(1)		Income Tax Expense
Total, net of income tax	(8)		4
	3		—		Earnings Attributable to Noncontrolling Interests
	$	(5)	$	4
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	2	Other Income, Net
Amortization of prior service cost	1		1		Other Income, 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	$	(4)	$	6









SoCalGas:


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




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 “Pension and PBOP” above).

For the three months ended March 31, 2023 and 2022, reclassifications out of AOCI to net income were negligible for SDG&E.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Common Stock Repurchases

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.

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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	2,198	$	2,060
SI Partners subsidiaries(1)	0.1 - 30.0		0.1 - 16.6		360		61
Total Sempra					$	2,558	$	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 ConocoPhillips Affiliate. On March 20, 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 KKR Denali. On March 20, 2023, an indirect subsidiary of SI Partners entered into an agreement for the sale to KKR Denali of an indirect interest of a minimum of 25% and up to 48.65% in the PA LNG Phase 1 project for aggregate cash consideration of a minimum of $64 million for a 25% indirect interest and up to $125 million for the full 48.65% indirect interest, plus KKR Denali’s 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 summer of 2023, subject to regulatory approvals and other customary 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.

Following completion of the sale of NCI to the ConocoPhillips affiliate and subject to closing the sale of NCI to KKR Denali, Sempra would hold an indirect interest in the PA LNG Phase 1 project of between 14.9% and 31.5%, depending on the amount of KKR Denali’s investment at closing.

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)
	March 31, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	57	$	41
Various affiliates	17		13
Total due from unconsolidated affiliates – current	$	74	$	54

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V. – 5.5% Note due January 9, 2024	$	(41)	$	—
Total due to unconsolidated affiliates – current	$	(41)	$	—

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	(21)		(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	(190)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(278)	$	(301)
SDG&E:



Sempra	$	(52)	$	(49)
SoCalGas	(75)		(72)
Various affiliates	(16)		(14)
Total due to unconsolidated affiliates – current	$	(143)	$	(135)

Income taxes due (to) from Sempra(2)	$	(8)	$	10
SoCalGas:
SDG&E	$	75	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	76	$	77

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

Income taxes due to Sempra(2)	$	(25)	$	(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 March 31,
		2023		2022
Sempra:
Revenues		$	13	$	7

Interest income		—		10
Interest expense		4		4
SDG&E:
Revenues		$	4	$	4
Cost of sales		30		24
SoCalGas:
Revenues		$	34	$	26
Cost of sales(1)		31		—

(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, NET

Other Income, Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended March 31,
		2023		2022
Sempra:
Allowance for equity funds used during construction		$	33	$	35
Investment gains (losses), net(1)		12		(13)
Gains on interest rate and foreign exchange instruments, net		5		6
Foreign currency transaction gains (losses), net(2)		1		(19)
Non-service components of net periodic benefit cost		(25)		41
Interest on regulatory balancing accounts, net		18		1
Sundry, net		(3)		(13)
Total		$	41	$	38
SDG&E:
Allowance for equity funds used during construction		$	23	$	21
Non-service components of net periodic benefit cost		(4)		11
Interest on regulatory balancing accounts, net		10		1
Sundry, net		(1)		1
Total		$	28	$	34
SoCalGas:
Allowance for equity funds used during construction		$	10	$	13
Non-service components of net periodic benefit cost		(19)		32
Interest on regulatory balancing accounts, net		8		—
Sundry, net		(7)		(11)
Total		$	(8)	$	34

(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 three months ended March 31, 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 AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
		2023			2022
Sempra:
Income tax expense		$	376		$	334

Income before income taxes and equity earnings		$	1,329		$	665
Equity earnings, before income tax(1)		132			143
Pretax income		$	1,461		$	808

Effective income tax rate		26		%	41		%
SDG&E:
Income tax expense		$	7		$	64
Income before income taxes		$	265		$	298
Effective income tax rate		3		%	21		%
SoCalGas:
Income tax expense		$	94		$	84
Income before income taxes		$	454		$	418
Effective income tax rate		21		%	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. We are assessing the potential impacts of this Revenue Procedure and do not expect it to have a material impact on Sempra’s, SDG&E’s or SoCalGas’ results of operations, financial condition and/or cash flows.

In the three months ended March 31, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested.

NEW ACCOUNTING STANDARDS	3 Months Ended
NEW ACCOUNTING STANDARDS	Mar. 31, 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.

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Revenue from Contract with Customer [Abstract]

REVENUES

3 Months Ended

Mar. 31, 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.

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 March 31, 2023
By major service line:
Utilities	$	1,765	$	3,841	$	30	$	(38)	$	5,598
Energy-related businesses	—		—		312		(21)		291
Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889

By market:
Gas	$	554	$	3,841	$	204	$	(35)	$	4,564
Electric	1,211		—		138		(24)		1,325
Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889

Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889
Utilities regulatory revenues	(112)		(47)		—		—		(159)
Other revenues	—		—		854		(24)		830
Total revenues	$	1,653	$	3,794	$	1,196	$	(83)	$	6,560

	Three months ended March 31, 2022
By major service line:
Utilities	$	1,501	$	1,912	$	28	$	(29)	$	3,412
Energy-related businesses	—		—		292		(15)		277
Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689

By market:
Gas	$	330	$	1,912	$	229	$	(26)	$	2,445
Electric	1,171		—		91		(18)		1,244
Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689

Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689
Utilities regulatory revenues	(56)		81		—		—		25
Other revenues	—		—		104		2		106
Total revenues	$	1,445	$	1,993	$	424	$	(42)	$	3,820

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations

For contracts greater than one year, at March 31, 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 March 31, 2023.


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first three months of 2023)	$	279	$	3
2024	303		4
2025	364		4
2026	363		4
2027	363		4
Thereafter	4,153		59
Total revenues to be recognized	$	5,825	$	78

(1) Excludes intercompany transactions.

Contract Liabilities from Revenues from Contracts with Customers

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the three months ended March 31, 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	2		39

Contract liabilities at March 31(1)	$	(250)	$	(239)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	1		1
Contract liabilities at March 31(2)	$	(78)	$	(82)

(1) Balances at March 31, 2023 include $12 in Other Current Liabilities and $238 in Deferred Credits and Other.

(2) Balances at March 31, 2023 include $4 in Other Current Liabilities and $74 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)
	March 31, 2023		December 31, 2022

Sempra:
Accounts receivable – trade, net(1)	$	2,417	$	2,291
Accounts receivable – other, net	12		25
Due from unconsolidated affiliates – current(2)	10		9
Other long-term assets(3)	4		9
Total	$	2,443	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	859	$	799
Accounts receivable – other, net	11		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	3		6
Total	$	879	$	819
SoCalGas:
Accounts receivable – trade, net	$	1,422	$	1,295
Accounts receivable – other, net	1		13
Other long-term assets(3)	1		3
Total	$	1,424	$	1,311

(1) At March 31, 2023 and December 31, 2022, includes $81 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.

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.

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INVESTMENTS IN UNCONSOLIDATED ENTITIES

REGULATORY MATTERS

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERSWe 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)
	March 31, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	(28)	$	(110)
Deferred income taxes recoverable in rates	372		296
Pension and PBOP plan obligations	7		11
Removal obligations	(2,319)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	124		123
Regulatory balancing accounts(1)(2):
Commodity – electric	184		220
Gas transportation	30		60
Safety and reliability	135		107
Public purpose programs	(100)		(69)
Wildfire mitigation plan	443		375
Liability insurance premium	100		99
Other balancing accounts	(169)		(50)
Other regulatory assets, net(2)	154		137
Total SDG&E	(961)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	208		161
Pension and PBOP plan obligations	(201)		(170)
Employee benefit costs	24		24
Removal obligations	(610)		(616)
Environmental costs	38		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(376)		(257)
Safety and reliability	595		575
Public purpose programs	(132)		(158)
Liability insurance premium	24		23
Other balancing accounts	267		115
Other regulatory assets, net(2)	261		223
Total SoCalGas	98		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78

Total Sempra	$	(785)	$	(906)

(1) At March 31, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $648 and $562, respectively, and for SoCalGas was $754 and $692, respectively.

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

SEMPRA CALIFORNIA

CPUC GRC

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

In May 2022, SDG&E and SoCalGas filed their 2024 GRC applications requesting CPUC approval of test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. SDG&E and SoCalGas requested revenue requirements for 2024 of $3.0 billion and $4.4 billion, respectively. SDG&E and SoCalGas proposed post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. 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. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. In April 2023, a proposed decision was issued that would allow 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 mid-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. For the measurement period that ends on September 30, 2023, SDG&E’s CCM benchmark rate is 4.367% based on Moody’s Baa- utility bond index and SoCalGas’ CCM benchmark rate is 4.074% based on Moody’s A- utility bond index.


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
	March 31, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	37	$	1	$	(1)	$	37
Municipal bonds(2)	274		2		(10)		266
Other securities(3)	245		2		(17)		230
Total debt securities	556		5		(28)		533
Equity securities	112		209		(5)		316
Short-term investments, primarily cash equivalents	19		—		—		19
Receivables (payables), net	(4)		—		—		(4)
Total	$	683	$	214	$	(33)	$	864

	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 2023-2056.

(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 March 31,
		2023		2022
Proceeds from sales		$	156	$	242
Gross realized gains		2		11
Gross realized losses		(3)		(4)

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 $535 million at March 31, 2023 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

INVESTMENTS IN UNCONSOLIDATED ENTITIES

3 Months Ended

Mar. 31, 2023

Investments [Abstract]

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 Notes 5 and 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 both the three months ended March 31, 2023 and 2022, Sempra contributed $85 million to Oncor Holdings, and Oncor Holdings distributed $85 million 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 March 31,
		2023		2022
Operating revenues		$	1,292	$	1,249
Operating expenses		(1,024)		(897)
Income from operations		268		352
Interest expense		(123)		(108)
Income tax expense		(24)		(42)
Net income		99		191
Noncontrolling interest held by Texas Transmission Investment LLC		(20)		(38)
Earnings attributable to Sempra(1)		79		153

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

SEMPRA INFRASTRUCTURE

Cameron LNG JV

In the three months ended March 31, 2023 and 2022, Cameron LNG JV distributed to Sempra Infrastructure $114 million and $119 million, respectively.

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 March 31, 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 March 31, 2023, the fair value of the Support Agreement was $24 million, of which $7 million is included in Other Current Assets and $17 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

DEBT AND CREDIT FACILITIES

3 Months Ended

Mar. 31, 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 March 31, 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)
		March 31, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	October 2027	$	4,000	$	(707)	$	—	$	3,293
SDG&E	October 2027	1,500		—		—		1,500
SoCalGas	October 2027	1,200		(223)		—		977
SI Partners	November 2024	1,000		—		—		1,000
IEnova and SI Partners	September 2023	350		—		(350)		—
IEnova and SI Partners	December 2023	150		—		(8)		142
IEnova and SI Partners	February 2024	1,500		—		(926)		574
Port Arthur LNG	March 2030	200		—		—		200
Total		$	9,900	$	(930)	$	(1,284)	$	7,686

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 March 31, 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 March 31, 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 four external 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.

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 $25 million was outstanding at March 31, 2023. The amounts outstanding are before reductions of any unamortized discounts. The facility expires in August 2023 and borrowings can be in U.S. dollars or Mexican pesos. At March 31, 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. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 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 March 31, 2023, we had $533 million in standby letters of credit outstanding under these agreements.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		March 31, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	May 2023 - January 2024	$	15
SoCalGas	June 2023 - March 2024	20
Sempra Infrastructure	April 2023 - October 2043	330
Parent and other	June 2023 - March 2024	168
Total		$	533

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 bears interest at benchmark rates plus 70 bps and is due in full upon maturity. SoCalGas used the proceeds for payment of a portion of the costs relating to litigation pertaining to the Leak.

Weighted-Average Interest Rates

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


WEIGHTED-AVERAGE INTEREST RATES

	March 31, 2023		December 31, 2022
Sempra	5.68	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.37		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.

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 March 31, 2023 and December 31, 2022, $634 million and $575 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 7.86% and 7.54%, respectively.

Port Arthur LNG

On March 20, 2023, Port Arthur LNG entered into a term loan facility agreement with a syndicate of 21 external 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 on March 21, 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 March 31, 2023, $215 million of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.44%.

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.

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Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

3 Months Ended

Mar. 31, 2023

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 that the future cash flows of a given revenue or expense item may vary, and other criteria.

ENERGY DERIVATIVES

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

▪SDG&E and SoCalGas use natural gas 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

March 31, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

355

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

248

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. On March 20, 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. On March 21, 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. At March 31, 2023, these interest rate swaps accrued interest based on a $200 million notional. 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)

March 31, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges

4,457

2023-2048

294

2023-2034

FOREIGN CURRENCY DERIVATIVES

We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican 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)
	March 31, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	88		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)
	March 31, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	10	$	29	$	—	$	(73)
Foreign exchange instruments	—		—		(13)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	217		23		(208)		(28)
Associated offsetting commodity contracts	(197)		(23)		197		23
Commodity contracts subject to rate recovery	38		26		(52)		(12)
Associated offsetting commodity contracts	(21)		(3)		21		3
Net amounts presented on the balance sheet	47		52		(55)		(87)
Additional cash collateral for commodity contracts not subject to rate recovery	317		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	95		—		—		—
Total(2)	$	459	$	52	$	(55)	$	(87)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	35	$	26	$	(21)	$	(3)
Associated offsetting commodity contracts	(19)		(3)		19		3
Net amounts presented on the balance sheet	16		23		(2)		—
Additional cash collateral for commodity contracts subject to rate recovery	84		—		—		—
Total(2)	$	100	$	23	$	(2)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(31)	$	(9)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	1		—		(29)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	11		—		—		—
Total	$	12	$	—	$	(29)	$	(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 (loss) gain recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings












	Three months ended March 31,					Three months ended March 31,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	(77)	$	22	Interest Expense	$	—	$	1
Interest rate instruments	(17)		94		Equity Earnings(1)	7		(14)
Foreign exchange instruments	(6)		(3)		Revenues: Energy- Related Businesses	—		1
					Other Income, Net	(1)		—
Foreign exchange instruments	(5)		(2)		Equity Earnings(1)	(1)		1

Interest rate and foreign exchange instruments	7		9		Other Income, Net	6		6
Total	$	(98)	$	120		$	11	$	(5)

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

For Sempra, we expect that net gains before NCI of $33 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $19 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 March 31, 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 17 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 March 31,
	Location		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses		$	449	$	(77)
Commodity contracts subject to rate recovery	Cost of Natural Gas		(27)		—
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power		9		18
Interest rate instrument	Interest Expense		(47)		—
Total			$	384	$	(59)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power		$	9	$	18
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas		$	(27)	$	—

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 March 31, 2023 and December 31, 2022 was $42 million and $106 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at March 31, 2023 and December 31, 2022 was $38 million and $69 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at March 31, 2023 or December 31, 2022. At March 31, 2023, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $42 million and $38 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

For Sempra, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.

FAIR VALUE MEASUREMENTS

3 Months Ended

Mar. 31, 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 March 31, 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 March 31, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	18	$	1	$	—	$	19
Equity securities	312		4		—		316
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	24		13		—		37
Municipal bonds	—		266		—		266
Other securities	—		230		—		230
Total debt securities	24		509		—		533
Total nuclear decommissioning trusts(1)	354		514		—		868
Short-term investments held in Rabbi Trust	48		—		—		48
Interest rate instruments	—		39		—		39
Commodity contracts not subject to rate recovery	—		20		—		20
Effect of netting and allocation of collateral(2)	317		—		—		317
Commodity contracts subject to rate recovery	7		3		30		40
Effect of netting and allocation of collateral(2)	79		10		6		95
Support Agreement, net of related guarantee fees	—		—		24		24
Total	$	805	$	586	$	60	$	1,451
Liabilities:
Interest rate instruments	$	—	$	73	$	—	$	73
Foreign exchange instruments	—		13		—		13
Commodity contracts not subject to rate recovery	—		16		—		16
Commodity contracts subject to rate recovery	—		40		—		40
Total	$	—	$	142	$	—	$	142

(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 March 31, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	18	$	1	$	—	$	19
Equity securities	312		4		—		316
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	24		13		—		37
Municipal bonds	—		266		—		266
Other securities	—		230		—		230
Total debt securities	24		509		—		533
Total nuclear decommissioning trusts(1)	354		514		—		868
Commodity contracts subject to rate recovery	7		2		30		39
Effect of netting and allocation of collateral(2)	78		—		6		84
Total	$	439	$	516	$	36	$	991
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	2
Total	$	—	$	2	$	—	$	2

	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 March 31, 2023
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	1		10		—		11
Total	$	1	$	11	$	—	$	12
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	38	$	—	$	38
Total	$	—	$	38	$	—	$	38

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

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

Level 3 Information

SDG&E

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


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)









	Three months ended March 31,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized (losses) gains	(4)		7
Settlements	(1)		(3)
Balance at March 31	$	30	$	58
Change in unrealized (losses) gains relating to instruments still held at March 31	$	(2)	$	9

(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 negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a 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 March 31 were as follows:


LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS

Settlement year	Price per MWh					Weighted-average price per MWh
2023	$	28.55	to	$	150.00	$	82.19
2022		26.55	to		137.80		62.79

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 March 31,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	9		8
Settlements	(2)		(3)
Balance at March 31(2)	$	24	$	12
Change in unrealized gains relating to instruments still held at March 31	$	9	$	7

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

(2) Includes $7 in Other Current Assets and $17 in Other Long-term Assets at March 31, 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
	March 31, 2023
Sempra:

Long-term note receivable(1)	$	322	$	—	$	—	$	313	$	313
Long-term amounts due to unconsolidated affiliates	319		—		284		—		284
Total long-term debt(2)	25,386		—		22,939		—		22,939
SDG&E:
Total long-term debt(3)	$	8,600	$	—	$	7,747	$	—	$	7,747
SoCalGas:
Total long-term debt(4)	$	6,059	$	—	$	5,673	$	—	$	5,673

	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 March 31, 2023 and December 31, 2022, respectively. Excludes unamortized transaction costs of $4 and $5 at March 31, 2023 and December 31, 2022, respectively.

(2) Before reductions of unamortized discount and debt issuance costs of $306 and $289 at March 31, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,346 and $1,343 at March 31, 2023 and December 31, 2022, respectively.

(3) Before reductions of unamortized discount and debt issuance costs of $86 and $70 at March 31, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,249 and $1,256 at March 31, 2023 and December 31, 2022, respectively.

(4) Before reductions of unamortized discount and debt issuance costs of $46 and $48 at March 31, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $97 and $87 at March 31, 2023 and December 31, 2021, respectively.

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

SAN ONOFRE NUCLEAR GENERATING STATION

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.

+ References + Details

SAN ONOFRE NUCLEAR GENERATING STATION

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]


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

SDG&E:
Fixed-price contracts and other derivatives	$	(28)	$	(110)
Deferred income taxes recoverable in rates	372		296
Pension and PBOP plan obligations	7		11
Removal obligations	(2,319)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	124		123
Regulatory balancing accounts(1)(2):
Commodity – electric	184		220
Gas transportation	30		60
Safety and reliability	135		107
Public purpose programs	(100)		(69)
Wildfire mitigation plan	443		375
Liability insurance premium	100		99
Other balancing accounts	(169)		(50)
Other regulatory assets, net(2)	154		137
Total SDG&E	(961)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	208		161
Pension and PBOP plan obligations	(201)		(170)
Employee benefit costs	24		24
Removal obligations	(610)		(616)
Environmental costs	38		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(376)		(257)
Safety and reliability	595		575
Public purpose programs	(132)		(158)
Liability insurance premium	24		23
Other balancing accounts	267		115
Other regulatory assets, net(2)	261		223
Total SoCalGas	98		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78

Total Sempra	$	(785)	$	(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


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	March 31, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	37	$	1	$	(1)	$	37
Municipal bonds(2)	274		2		(10)		266
Other securities(3)	245		2		(17)		230
Total debt securities	556		5		(28)		533
Equity securities	112		209		(5)		316
Short-term investments, primarily cash equivalents	19		—		—		19
Receivables (payables), net	(4)		—		—		(4)
Total	$	683	$	214	$	(33)	$	864

	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 2023-2056.

(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 March 31,
		2023		2022
Proceeds from sales		$	156	$	242
Gross realized gains		2		11
Gross realized losses		(3)		(4)

ASSET RETIREMENT OBLIGATION

COMMITMENTS AND CONTINGENCIES

3 Months Ended

Mar. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

LEGAL PROCEEDINGS

We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.

At March 31, 2023, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $280 million for Sempra, including $204 million for SoCalGas. Amounts for Sempra and SoCalGas include $129 million for matters related to the Leak, which we discuss below.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

From October 23, 2015 through February 11, 2016, SoCalGas experienced a natural gas leak from one of the injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility in Los Angeles County.

Litigation. In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) pending against SoCalGas and Sempra related to the Leak for a payment of up to $1.8 billion. Over 99% of the Individual Plaintiffs participated and submitted valid releases, and SoCalGas paid $1.79 billion in 2022 under the agreement. The Individual Plaintiffs who have not participated in the settlement (the Remaining Individual Plaintiffs) are able to continue to pursue their claims. As of February 21, 2023, approximately 265 of the Remaining Individual Plaintiffs had not been located or had failed to respond, according to plaintiffs’ counsel.

The Individual Plaintiffs’ cases were coordinated before a single court in the LA Superior Court for pretrial management under a consolidated master complaint filed in November 2017. The consolidated master complaint asserts causes of action for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment, loss of consortium and wrongful death against SoCalGas and Sempra. The consolidated master complaint seeks compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, injunctive relief, costs of future medical monitoring, civil penalties, and attorneys’ fees.

In addition, as of April 28, 2023, 25 new lawsuits on behalf of approximately 310 new plaintiffs have been filed against SoCalGas and Sempra since the September 2021 settlement. These cases are being joined in the same coordinated proceeding in the LA Superior Court. The new lawsuits assert the same causes of action and seek the same relief as the consolidated master complaint.

Four shareholder derivative actions were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra and/or SoCalGas. Three of the four shareholder derivative actions that were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra and/or SoCalGas were joined in an Amended Consolidated Shareholder Derivative Complaint filed in the same coordinated proceeding in the LA Superior Court, which was dismissed with prejudice in January 2021. The plaintiffs have appealed this dismissal. The LA Superior Court dismissed the remaining fourth action with prejudice in November 2022. The plaintiffs have appealed this dismissal.

Regulatory Proceedings. In February 2017, the CPUC opened a proceeding pursuant to the SB 380 OII to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility while still maintaining energy and electric reliability for the region, but excluding issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. The first phase of the proceeding established a framework for the hydraulic, production cost and economic modeling assumptions for the potential reduction in usage or elimination of the Aliso Canyon natural gas storage facility, as well as evaluating the impacts of reducing or eliminating the Aliso Canyon natural gas storage facility using the established framework and models. The next phase of the proceeding included engaging a consultant to analyze alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2035 timeframe, and to address potential implementation of alternatives to the Aliso Canyon natural gas storage facility if the CPUC determines that the

Aliso Canyon natural gas storage facility should be permanently closed. The CPUC also added all California IOUs as parties to the proceeding and encouraged all load serving entities in the Los Angeles Basin to join the proceeding.

In November 2021, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting an interim range of gas inventory levels of up to 41.16 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final inventory determination within the SB 380 OII proceeding.

At March 31, 2023, the Aliso Canyon natural gas storage facility had a net book value of $965 million. If the Aliso Canyon natural gas storage facility were to be permanently closed or if future cash flows from its operation were otherwise insufficient to recover its carrying value, we may record an impairment of the facility, which could be material, or we could incur materially higher than expected operating costs and/or be required to make material additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized.

Regulatory Proceeding – Subject to an Agreement to Resolve. In June 2019, the CPUC opened an OII (the Leak OII) to investigate and consider, among other things, whether SoCalGas should be sanctioned for the Leak and what damages, fines or other penalties, if any, should be imposed for any violations, unreasonable or imprudent practices or failure to cooperate sufficiently with SED, as well as to determine the amount of various costs incurred by SoCalGas and other parties in connection with the Leak and the ratemaking treatment or other disposition of such costs, which could result in little or no recovery of such costs by SoCalGas. In October 2022, SoCalGas executed a settlement agreement with SED and the Public Advocates Office at the CPUC to resolve all aspects of the Leak OII. The settlement agreement provides for financial penalties, certain costs that SoCalGas will reimburse, a violation of California Public Utilities Code section 451, and costs previously incurred by SoCalGas for which it will not seek recovery from ratepayers, among other provisions. The settlement agreement was filed with and is subject to approval by the CPUC.

Insurance and Accounting and Other Impacts. Since 2015, SoCalGas has incurred significant costs related to the Leak, including costs to defend against and settle civil litigation arising from the Leak. Other than insurance for directors’ and officers’ liability, we have exhausted all of our insurance for this matter. We continue to pursue other sources of insurance coverage for costs related to this matter, but we may not be successful in obtaining additional insurance recovery for any of these costs. At March 31, 2023, $129 million is accrued in Reserve for Aliso Canyon Costs and $3 million is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets.

In the three months ended March 31, 2022, SoCalGas recorded total charges of $92 million ($66 million after tax) in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations related to the litigation and regulatory proceedings associated with the Leak.

Except for the amounts paid or estimated to settle certain legal and regulatory matters, the accruals do not include any amounts necessary to resolve the matters that we describe above in “Litigation” and “Regulatory Proceedings,” threatened litigation, other potential litigation or other costs, in each case to the extent it is not possible to predict at this time the outcome of these actions or reasonably estimate the possible costs or a range of possible costs. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued, which could be significant.

Sempra Infrastructure

Energía Costa Azul

We describe below certain land and customer disputes and permit challenges affecting our ECA Regas Facility. Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities under construction and in development are expected to be situated or on which portions of the ECA Regas Facility that would be necessary for the operation of such ECA LNG liquefaction facilities are situated. One or more unfavorable final decisions on these disputes or challenges could materially adversely affect our existing natural gas regasification operations and proposed natural gas liquefaction projects at the site of the ECA Regas Facility and have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Land Disputes. Sempra Infrastructure has been engaged in a long-running land dispute relating to property adjacent to its ECA Regas Facility that allegedly overlaps with land owned by the ECA Regas Facility (the facility, however, is not situated on the land that is the subject of this dispute), as follows:

▪A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue title to him for the disputed property. In November 2013, the federal Agrarian Court ordered that SEDATU issue the requested title to the claimant and cause it to be registered. Both SEDATU and Sempra Infrastructure challenged the ruling due to lack of notification of the underlying process. In May 2019, a federal court in Mexico reversed the ruling and ordered a retrial, which is pending resolution.

▪In a separate proceeding, the claimant filed suit to reinitiate an administrative procedure at SEDATU to obtain the property title that was previously dismissed. In April 2021, the Agrarian Court ordered that the administrative procedure be restarted. The proceeding in the Agrarian Court has concluded; however, the administrative procedure at SEDATU may continue if SEDATU decides to reopen the matter.

In addition, an area of real property on which part of the ECA Regas Facility is situated is subject to a claim in the federal Agrarian Court, in which the plaintiff seeks to annul the property title for a portion of the land on which the ECA Regas Facility is situated and to obtain possession of a different parcel that allegedly overlaps with the site of the ECA Regas Facility. The proceeding, which seeks an order that SEDATU annul the ECA Regas Facility’s competing property title, was initiated in 2006 and, in July 2021, a decision was issued in favor of the ECA Regas Facility. The plaintiff appealed, and in February 2022, the appellate court confirmed the ruling in favor of the ECA Regas Facility and dismissed the appeal. The plaintiff filed a federal appeal against the appellate court ruling. A ruling from the Federal Collegiate Circuit Court is pending.

Environmental and Social Impact Permits. Several administrative challenges are pending before Mexico’s Secretariat of Environment and Natural Resources (the Mexican environmental protection agency) and Federal Tax and Administrative Courts, seeking revocation of the environmental impact authorization issued to the ECA Regas Facility in 2003. These cases generally allege that the conditions and mitigation measures in the environmental impact authorization are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines.

In 2018 and 2021, three related claimants filed separate challenges in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued by each of ASEA and SENER to ECA LNG authorizing natural gas liquefaction activities at the ECA Regas Facility, as follows:

▪In the first case, the court issued a provisional injunction in September 2018. In December 2018, ASEA approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility in two phases. In May 2019, the court canceled the provisional injunction. The claimant appealed the court’s decision canceling the injunction but was not successful. The claimant’s underlying challenge to the permits remains pending.

▪In the second case, the initial request for a provisional injunction was denied. That decision was reversed on appeal in January 2020, resulting in the issuance of a new injunction against the permits that were issued by ASEA and SENER. This injunction has uncertain application absent clarification by the court. The claimants petitioned the court to rule that construction of natural gas liquefaction facilities violated the injunction, and in February 2022, the court ruled in favor of the ECA Regas Facility, holding that the natural gas liquefaction activities did not violate the injunction. The claimants have appealed this ruling.

▪In the third case, a group of residents filed a complaint in June 2021 against various federal and state authorities alleging deficiencies in the public consultation process for the issuance of the permits. The request for an initial injunction was denied and the claimants have appealed, which is pending the appellate court’s ruling.

Litigation Related to Regulatory and Other Actions by the Mexican Government

Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective on March 10, 2021, and SENER, the CRE and Centro Nacional de Control de Energía (Mexico’s National Center for Energy Control) were to have 180 calendar days to modify, as necessary, all resolutions, policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. However, a Mexican court issued a suspension of the amendments on March 19, 2021. In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law, but the qualified majority of eight votes out of 11 as is required in matters involving constitutionality was not reached and the proceeding was dismissed, which means that the Mexican Supreme Court did not issue a binding precedent and the amended Electricity Industry Law remains in force. Sempra Infrastructure filed three lawsuits against the amendments to the Electricity Industry Law and, in each of them, Sempra Infrastructure obtained a favorable judgment in the lower courts, which has been appealed. If the proposed amendments are affirmed by the lower courts or by the Mexican Supreme Court (which in these cases would only require a simple majority vote), the CRE may be required to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, under a legal standard that is ambiguous and not well defined under the law. If such self-supply permits granted under the former electricity law are revoked, it may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, may result in decreased revenues and cash flows, and may negatively impact our ability to recover the carrying values of our investments in Mexico, any of which could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Sonora Pipeline – Resolved

Guaymas-El Oro Segment. Sempra Infrastructure’s Sonora natural gas pipeline consists of two segments, the Sasabe-Puerto Libertad-Guaymas segment and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. In 2015, the Yaqui tribe, with the exception of some members living in the Bácum community, granted its consent and a right-of-way easement agreement for the construction of the Guaymas-El Oro segment of the Sonora natural gas pipeline that crosses its territory. Representatives of the Bácum community filed a legal challenge in Mexican federal court demanding the right to withhold consent for the project, the stoppage of work in the Yaqui territory and damages. In 2016, the judge granted a suspension order that prohibited the construction of such segment through the Bácum community territory. Because the pipeline does not pass through the Bácum community, Sempra Infrastructure did not believe the 2016 suspension order prohibited construction in the remainder of the Yaqui territory. Construction of the Guaymas-El Oro segment was completed, and commercial operations began in May 2017.

Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 2017 and, as a result, Sempra Infrastructure declared a force majeure event. In 2017, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory, which has prevented Sempra Infrastructure from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of Sempra Infrastructure and held that the Yaqui tribe was properly consulted and that consent from the Yaqui tribe was properly received. Representatives of the Bácum community appealed this decision, causing the suspension order preventing Sempra Infrastructure from repairing the damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory to remain in place until the appeals process is exhausted. In December 2021, the court of appeals referred the matter to Mexico’s Supreme Court. In June 2022, the Supreme Court remanded the case back to the court of appeals for final resolution. The CFE asked the court of appeals to dismiss the Bácum community’s appeal based on the plan to re-route the portion of the pipeline that is in the Yaqui territory. In December 2022, the court of appeals reversed the federal district court’s ruling and ordered the district court to issue a new ruling that takes into account the planned re-routing of the pipeline. In February 2023, the district court issued a new ruling and resolved to dismiss the case. The representatives of the Bácum community did not appeal the ruling and, in March 2023, the district court declared that the case was definitively concluded.

Other Litigation

RBS Sempra Commodities

Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against RBS (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE, a subsidiary of RBS Sempra Commodities. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million (approximately $55 million in U.S. dollars at March 31, 2023), plus costs and interest. In October 2020, the High Court of Justice assessed costs and interest to be approximately £21 million (approximately $26 million in U.S. dollars at March 31, 2023) as of that date, with interest continuing to accrue. The Defendants appealed and, in May 2021, the Court of Appeal set aside the High Court of Justice’s decision and ordered a retrial. In July 2022, the Supreme Court of the U.K. denied the Liquidating Companies application for permission to appeal the Court of Appeal’s decision. No date has been scheduled for the retrial. J.P. Morgan Chase & Co., which acquired RBS SEE and later sold it to Mercuria Energy Group, Ltd., previously notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and J.P. Morgan Chase & Co. has in turn sought indemnity from Sempra and RBS.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of April 28, 2023, two lawsuits are pending. Additionally, approximately 28,000 proofs of claim were filed, but not discharged, in the EFH bankruptcy proceeding on behalf of persons who allege exposure to asbestos

under similar circumstances and assert the right to file such lawsuits in the future. The costs to defend or resolve such claims and the amount of damages that may be incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Ordinary Course Litigation

We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases.

LEASES

We discuss leases further in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report.

Lessee Accounting

We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities.

Leases That Have Not Yet Commenced

SDG&E has entered into five energy storage agreements, of which SDG&E expects one will commence in the first half of 2023, one will commence in the second half of 2023, two will commence in 2024 and one will commence in 2025. SDG&E expects the future minimum lease payments to be $11 million in 2023, $45 million in 2024, $54 million in each of 2025 through 2027 and $447 million thereafter until expiration in 2039.

SoCalGas has entered into a fleet vehicle agreement, under which SoCalGas expects leases will commence in the second quarter of 2023 through the fourth quarter of 2023. SoCalGas expects the future minimum lease payments to be $1 million in each of 2023 through 2027 and $6 million thereafter until expiration in 2031.

Lessor Accounting

Sempra Infrastructure is a lessor for certain of its natural gas and ethane pipelines, compressor stations, liquid petroleum gas storage facilities, a rail facility and refined products terminals, which we account for as operating or sales-type leases.

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


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended March 31,
		2023		2022
Sales-type leases:

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

Operating leases:
Fixed lease payments		$	80	$	70
Variable lease payments		2		1
Total revenues from operating leases(1)		$	82	$	71

Depreciation expense		$	15	$	13

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first three months of 2023 to contractual commitments discussed in Notes 1 and 16 of the Notes to Consolidated Financial Statements in the Annual Report.

Natural Gas Contracts

Sempra Infrastructure’s natural gas contracts and natural gas storage and transportation commitments have increased by approximately $321 million since December 31, 2022, primarily from entering into new storage and transportation contracts in the first three months of 2023. We expect future payments to decrease by $35 million in 2023, and increase by $2 million in 2024 and $354 million after 2027 through expiration in 2059 compared to December 31, 2022.

LNG Purchase Agreement

Sempra Infrastructure has an SPA for the supply of LNG to the ECA Regas Facility. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2023 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At March 31, 2023, we expect the commitment amount to decrease by $660 million in 2023 and increase by $40 million in 2024, $78 million in 2025, $62 million in 2026, $44 million in 2027 and $36 million thereafter (through contract termination in 2029) compared to December 31, 2022, reflecting changes in estimated forward prices since December 31, 2022 and actual transactions for the first three months of 2023. These LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted as of March 31, 2023, under the agreement are delivered. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amount provided under the agreement due to the supplier electing to divert cargoes as allowed by the agreement.

ENVIRONMENTAL ISSUES

We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $52 million for Sempra, $18 million for SDG&E and $20 million for SoCalGas at March 31, 2023.

SEGMENT INFORMATION

3 Months Ended

Mar. 31, 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 March 31,
		2023		2022
REVENUES
SDG&E		$	1,653	$	1,445
SoCalGas		3,794		1,993
Sempra Infrastructure		1,196		424
Adjustments and eliminations		1		2
Intersegment revenues(1)		(84)		(44)
Total		$	6,560	$	3,820
DEPRECIATION AND AMORTIZATION
SDG&E		$	262	$	239
SoCalGas		206		187
Sempra Infrastructure		69		65
All other		2		2
Total		$	539	$	493
INTEREST INCOME
SDG&E		$	1	$	—
SoCalGas		4		—
Sempra Infrastructure		15		21
All other		4		4
Total		$	24	$	25
INTEREST EXPENSE
SDG&E		$	118	$	106
SoCalGas		69		40
Sempra Infrastructure		95		27
All other		84		70
Total		$	366	$	243
INCOME TAX EXPENSE (BENEFIT)
SDG&E		$	7	$	64
SoCalGas		94		84

Sempra Infrastructure		330		91
All other		(55)		95
Total		$	376	$	334
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities		$	1	$	2
Sempra Infrastructure		131		141

		132		143
Equity earnings, net of income tax:
Sempra Texas Utilities		83		162
Sempra Infrastructure		4		21
		87		183
Total		$	219	$	326

(1) Revenues for reportable segments include intersegment revenues of $4, $34, and $46 for the three months ended March 31, 2023 and $4, $26, and $14 for the three months ended March 31, 2022 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E		$	258	$	234
SoCalGas		360		334
Sempra Texas Utilities		83		162
Sempra Infrastructure		315		95
All other		(47)		(213)
Total		$	969	$	612
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	624	$	552
SoCalGas		458		468
Sempra Infrastructure		744		182
All other		4		2
Total		$	1,830	$	1,204

		March 31, 2023		December 31, 2022
ASSETS
SDG&E		$	27,188	$	26,422
SoCalGas		22,776		22,346
Sempra Texas Utilities		13,852		13,781
Sempra Infrastructure		16,547		15,760
All other		1,282		1,376
Intersegment receivables		(1,096)		(1,111)
Total		$	80,549	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities		$	13,843	$	13,772
Sempra Infrastructure		1,893		1,905
Total		$	15,736	$	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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Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	3 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	Mar. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, 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 the consolidated financial statements of each reporting entity. 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 March 31, 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. We are assessing the potential impacts of this Revenue Procedure and do not expect it to have a material impact on Sempra’s, SDG&E’s or SoCalGas’ results of operations, financial condition and/or cash flows.
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 that the future cash flows of a given revenue or expense item may vary, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪SDG&E and SoCalGas use natural gas 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. On March 20, 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. On March 21, 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. At March 31, 2023, these interest rate swaps accrued interest based on a $200 million notional. 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 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.”We summarize CRR volumes in Note 7. 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.
Legal Costs Policy	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.
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.
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 (Tables)

3 Months Ended

Mar. 31, 2023

Schedule of Cash and Cash Equivalents


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	March 31, 2023		December 31, 2022
Cash and cash equivalents	$	534	$	370
Restricted cash, current	85		40
Restricted cash, noncurrent	84		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	703	$	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	117		48
Write-offs	(20)		(19)
Allowances for credit losses at March 31	$	278	$	165
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	38		21
Write-offs	(11)		(9)
Allowances for credit losses at March 31	$	105	$	78
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	77		26
Write-offs	(9)		(10)
Allowances for credit losses at March 31	$	166	$	85

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)
	March 31,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	238	$	140
Accounts receivable – other, net	40		40
Other long-term assets	—		1
Total allowances for credit losses	$	278	$	181
SDG&E:
Accounts receivable – trade, net	$	80	$	52
Accounts receivable – other, net	25		25
Other long-term assets	—		1
Total allowances for credit losses	$	105	$	78
SoCalGas:
Accounts receivable – trade, net	$	151	$	83
Accounts receivable – other, net	15		15
Total allowances for credit losses	$	166	$	98

Inventory Table

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Natural gas	$	41	$	106	$	1	$	1	$	24	$	74
LNG	7		62		—		—		—		—
Materials and supplies	267		235		142		133		106		85
Total	$	315	$	403	$	143	$	134	$	130	$	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 March 31,
		2023		2022
Sempra		$	73	$	57
SDG&E		31		28
SoCalGas		15		18

Net Periodic Benefit Cost Table


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022












Service cost	$	28	$	41	$	4	$	7
Interest cost	40		30		9		7
Expected return on assets	(43)		(46)		(17)		(16)
Amortization of:
Prior service cost (credit)	1		3		(1)		(1)
Actuarial loss (gain)	2		6		(6)		(4)
Net periodic benefit cost (credit)	28		34		(11)		(7)
Regulatory adjustments	29		(27)		11		7
Total expense recognized	$	57	$	7	$	—	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022











Service cost	$	8	$	10	$	1	$	2
Interest cost	10		7		2		1
Expected return on assets	(10)		(11)		(2)		(2)
Amortization of:
Actuarial loss (gain)	1		—		(1)		(1)
Net periodic benefit cost	9		6		—		—
Regulatory adjustments	4		(5)		—		—
Total expense recognized	$	13	$	1	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended March 31,
	2023		2022		2023		2022












Service cost	$	17	$	28	$	3	$	5
Interest cost	25		20		7		5
Expected return on assets	(29)		(31)		(15)		(13)
Amortization of:
Prior service cost (credit)	1		2		(1)		(1)
Actuarial loss (gain)	—		4		(5)		(3)
Net periodic benefit cost (credit)	14		23		(11)		(7)
Regulatory adjustments	25		(22)		11		7
Total expense recognized	$	39	$	1	$	—	$	—

Earnings Per Share Computations Table


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended March 31,
		2023		2022
Numerator:
Earnings attributable to common shares		$	969	$	612

Denominator:
Weighted-average common shares outstanding for basic EPS(1)		314,919		316,353
Dilutive effect of stock options and RSUs(2)		1,205		1,081
Weighted-average common shares outstanding for diluted EPS		316,124		317,434

EPS:
Basic		$	3.08	$	1.93
Diluted		$	3.07	$	1.93

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, excluding 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 accumulated other comprehensive income (loss)
	Three months ended March 31, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	10		(40)		(13)		(43)
Amounts reclassified from AOCI	—		(5)		1		(4)
Net OCI	10		(45)		(12)		(47)
Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	3		74		6		83
Amounts reclassified from AOCI	—		4		2		6
Net OCI	3		78		8		89
Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
SDG&E:




Balance at December 31, 2022 and March 31, 2023					$	(7)	$	(7)









Balance at December 31, 2021 and March 31, 2022					$	(10)	$	(10)
SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)

Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at March 31, 2023			$	(12)	$	(11)	$	(23)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at March 31, 2022			$	(13)	$	(17)	$	(30)

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

Reclassifications out of AOCI Table


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended March 31,
	2023		2022
Sempra:
Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	(7)		14		Equity Earnings(1)
Foreign exchange instruments	—		(1)		Revenues: Energy-Related Businesses
	1		—		Other Income, Net
Foreign exchange instruments	1		(1)		Equity Earnings(1)

Interest rate and foreign exchange instruments	(6)		(6)		Other Income, Net
Total, before income tax	(11)		5
	3		(1)		Income Tax Expense
Total, net of income tax	(8)		4
	3		—		Earnings Attributable to Noncontrolling Interests
	$	(5)	$	4
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	2	Other Income, Net
Amortization of prior service cost	1		1		Other Income, 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	$	(4)	$	6









SoCalGas:


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




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 “Pension and PBOP” above).

Ownership Interests Held By Others Table


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	2,198	$	2,060
SI Partners subsidiaries(1)	0.1 - 30.0		0.1 - 16.6		360		61
Total Sempra					$	2,558	$	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)
	March 31, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	57	$	41
Various affiliates	17		13
Total due from unconsolidated affiliates – current	$	74	$	54

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V. – 5.5% Note due January 9, 2024	$	(41)	$	—
Total due to unconsolidated affiliates – current	$	(41)	$	—

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	(21)		(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	(190)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(278)	$	(301)
SDG&E:



Sempra	$	(52)	$	(49)
SoCalGas	(75)		(72)
Various affiliates	(16)		(14)
Total due to unconsolidated affiliates – current	$	(143)	$	(135)

Income taxes due (to) from Sempra(2)	$	(8)	$	10
SoCalGas:
SDG&E	$	75	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	76	$	77

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

Income taxes due to Sempra(2)	$	(25)	$	(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 March 31,
		2023		2022
Sempra:
Revenues		$	13	$	7

Interest income		—		10
Interest expense		4		4
SDG&E:
Revenues		$	4	$	4
Cost of sales		30		24
SoCalGas:
Revenues		$	34	$	26
Cost of sales(1)		31		—

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

Other Income and Expense Table

Other Income, Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended March 31,
		2023		2022
Sempra:
Allowance for equity funds used during construction		$	33	$	35
Investment gains (losses), net(1)		12		(13)
Gains on interest rate and foreign exchange instruments, net		5		6
Foreign currency transaction gains (losses), net(2)		1		(19)
Non-service components of net periodic benefit cost		(25)		41
Interest on regulatory balancing accounts, net		18		1
Sundry, net		(3)		(13)
Total		$	41	$	38
SDG&E:
Allowance for equity funds used during construction		$	23	$	21
Non-service components of net periodic benefit cost		(4)		11
Interest on regulatory balancing accounts, net		10		1
Sundry, net		(1)		1
Total		$	28	$	34
SoCalGas:
Allowance for equity funds used during construction		$	10	$	13
Non-service components of net periodic benefit cost		(19)		32
Interest on regulatory balancing accounts, net		8		—
Sundry, net		(7)		(11)
Total		$	(8)	$	34

Income Tax Expense and Effective Income Tax Rates Table

We provide our calculations of ETRs in the following table.


INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended March 31,
		2023			2022
Sempra:
Income tax expense		$	376		$	334

Income before income taxes and equity earnings		$	1,329		$	665
Equity earnings, before income tax(1)		132			143
Pretax income		$	1,461		$	808

Effective income tax rate		26		%	41		%
SDG&E:
Income tax expense		$	7		$	64
Income before income taxes		$	265		$	298
Effective income tax rate		3		%	21		%
SoCalGas:
Income tax expense		$	94		$	84
Income before income taxes		$	454		$	418
Effective income tax rate		21		%	20		%

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

REVENUES (Tables)

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended March 31, 2023
By major service line:
Utilities	$	1,765	$	3,841	$	30	$	(38)	$	5,598
Energy-related businesses	—		—		312		(21)		291
Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889

By market:
Gas	$	554	$	3,841	$	204	$	(35)	$	4,564
Electric	1,211		—		138		(24)		1,325
Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889

Revenues from contracts with customers	$	1,765	$	3,841	$	342	$	(59)	$	5,889
Utilities regulatory revenues	(112)		(47)		—		—		(159)
Other revenues	—		—		854		(24)		830
Total revenues	$	1,653	$	3,794	$	1,196	$	(83)	$	6,560

	Three months ended March 31, 2022
By major service line:
Utilities	$	1,501	$	1,912	$	28	$	(29)	$	3,412
Energy-related businesses	—		—		292		(15)		277
Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689

By market:
Gas	$	330	$	1,912	$	229	$	(26)	$	2,445
Electric	1,171		—		91		(18)		1,244
Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689

Revenues from contracts with customers	$	1,501	$	1,912	$	320	$	(44)	$	3,689
Utilities regulatory revenues	(56)		81		—		—		25
Other revenues	—		—		104		2		106
Total revenues	$	1,445	$	1,993	$	424	$	(42)	$	3,820

Schedule of Timing of Remaining Performance Obligations


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first three months of 2023)	$	279	$	3
2024	303		4
2025	364		4
2026	363		4
2027	363		4
Thereafter	4,153		59
Total revenues to be recognized	$	5,825	$	78

(1) Excludes intercompany transactions.

Schedule of Contract Liabilities


CONTRACT LIABILITIES
(Dollars in millions)
	2023		2022
Sempra:
Contract liabilities at January 1	$	(252)	$	(278)
Revenue from performance obligations satisfied during reporting period	2		39

Contract liabilities at March 31(1)	$	(250)	$	(239)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	1		1
Contract liabilities at March 31(2)	$	(78)	$	(82)

(1) Balances at March 31, 2023 include $12 in Other Current Liabilities and $238 in Deferred Credits and Other.

(2) Balances at March 31, 2023 include $4 in Other Current Liabilities and $74 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)
	March 31, 2023		December 31, 2022

Sempra:
Accounts receivable – trade, net(1)	$	2,417	$	2,291
Accounts receivable – other, net	12		25
Due from unconsolidated affiliates – current(2)	10		9
Other long-term assets(3)	4		9
Total	$	2,443	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	859	$	799
Accounts receivable – other, net	11		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	3		6
Total	$	879	$	819
SoCalGas:
Accounts receivable – trade, net	$	1,422	$	1,295
Accounts receivable – other, net	1		13
Other long-term assets(3)	1		3
Total	$	1,424	$	1,311

(1) At March 31, 2023 and December 31, 2022, includes $81 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.

REGULATORY MATTERS (Tables)

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]

Schedule of Regulatory Assets


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

SDG&E:
Fixed-price contracts and other derivatives	$	(28)	$	(110)
Deferred income taxes recoverable in rates	372		296
Pension and PBOP plan obligations	7		11
Removal obligations	(2,319)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	124		123
Regulatory balancing accounts(1)(2):
Commodity – electric	184		220
Gas transportation	30		60
Safety and reliability	135		107
Public purpose programs	(100)		(69)
Wildfire mitigation plan	443		375
Liability insurance premium	100		99
Other balancing accounts	(169)		(50)
Other regulatory assets, net(2)	154		137
Total SDG&E	(961)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	208		161
Pension and PBOP plan obligations	(201)		(170)
Employee benefit costs	24		24
Removal obligations	(610)		(616)
Environmental costs	38		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(376)		(257)
Safety and reliability	595		575
Public purpose programs	(132)		(158)
Liability insurance premium	24		23
Other balancing accounts	267		115
Other regulatory assets, net(2)	261		223
Total SoCalGas	98		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78

Total Sempra	$	(785)	$	(906)

(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)
	March 31, 2023		December 31, 2022

SDG&E:
Fixed-price contracts and other derivatives	$	(28)	$	(110)
Deferred income taxes recoverable in rates	372		296
Pension and PBOP plan obligations	7		11
Removal obligations	(2,319)		(2,248)
Environmental costs	106		107
Sunrise Powerlink fire mitigation	124		123
Regulatory balancing accounts(1)(2):
Commodity – electric	184		220
Gas transportation	30		60
Safety and reliability	135		107
Public purpose programs	(100)		(69)
Wildfire mitigation plan	443		375
Liability insurance premium	100		99
Other balancing accounts	(169)		(50)
Other regulatory assets, net(2)	154		137
Total SDG&E	(961)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	208		161
Pension and PBOP plan obligations	(201)		(170)
Employee benefit costs	24		24
Removal obligations	(610)		(616)
Environmental costs	38		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(376)		(257)
Safety and reliability	595		575
Public purpose programs	(132)		(158)
Liability insurance premium	24		23
Other balancing accounts	267		115
Other regulatory assets, net(2)	261		223
Total SoCalGas	98		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78

Total Sempra	$	(785)	$	(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)

3 Months Ended

Mar. 31, 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 March 31,
		2023		2022
Operating revenues		$	1,292	$	1,249
Operating expenses		(1,024)		(897)
Income from operations		268		352
Interest expense		(123)		(108)
Income tax expense		(24)		(42)
Net income		99		191
Noncontrolling interest held by Texas Transmission Investment LLC		(20)		(38)
Earnings attributable to Sempra(1)		79		153

DEBT AND CREDIT FACILITIES (Tables)

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities


COMMITTED LINES OF CREDIT
(Dollars in millions)
		March 31, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	October 2027	$	4,000	$	(707)	$	—	$	3,293
SDG&E	October 2027	1,500		—		—		1,500
SoCalGas	October 2027	1,200		(223)		—		977
SI Partners	November 2024	1,000		—		—		1,000
IEnova and SI Partners	September 2023	350		—		(350)		—
IEnova and SI Partners	December 2023	150		—		(8)		142
IEnova and SI Partners	February 2024	1,500		—		(926)		574
Port Arthur LNG	March 2030	200		—		—		200
Total		$	9,900	$	(930)	$	(1,284)	$	7,686


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		March 31, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	May 2023 - January 2024	$	15
SoCalGas	June 2023 - March 2024	20
Sempra Infrastructure	April 2023 - October 2043	330
Parent and other	June 2023 - March 2024	168
Total		$	533

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


WEIGHTED-AVERAGE INTEREST RATES

	March 31, 2023		December 31, 2022
Sempra	5.68	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.37		4.71

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

March 31, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

355

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

248

224

Notional Amounts of Derivatives Table

INTEREST RATE DERIVATIVES

(Dollars in millions)

March 31, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges

4,457

2023-2048

294

2023-2034

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)
	March 31, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	88		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)
	March 31, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	10	$	29	$	—	$	(73)
Foreign exchange instruments	—		—		(13)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	217		23		(208)		(28)
Associated offsetting commodity contracts	(197)		(23)		197		23
Commodity contracts subject to rate recovery	38		26		(52)		(12)
Associated offsetting commodity contracts	(21)		(3)		21		3
Net amounts presented on the balance sheet	47		52		(55)		(87)
Additional cash collateral for commodity contracts not subject to rate recovery	317		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	95		—		—		—
Total(2)	$	459	$	52	$	(55)	$	(87)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	35	$	26	$	(21)	$	(3)
Associated offsetting commodity contracts	(19)		(3)		19		3
Net amounts presented on the balance sheet	16		23		(2)		—
Additional cash collateral for commodity contracts subject to rate recovery	84		—		—		—
Total(2)	$	100	$	23	$	(2)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	3	$	—	$	(31)	$	(9)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	1		—		(29)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	11		—		—		—
Total	$	12	$	—	$	(29)	$	(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 (loss) gain recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings












	Three months ended March 31,					Three months ended March 31,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	(77)	$	22	Interest Expense	$	—	$	1
Interest rate instruments	(17)		94		Equity Earnings(1)	7		(14)
Foreign exchange instruments	(6)		(3)		Revenues: Energy- Related Businesses	—		1
					Other Income, Net	(1)		—
Foreign exchange instruments	(5)		(2)		Equity Earnings(1)	(1)		1

Interest rate and foreign exchange instruments	7		9		Other Income, Net	6		6
Total	$	(98)	$	120		$	11	$	(5)

(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 March 31,
	Location		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses		$	449	$	(77)
Commodity contracts subject to rate recovery	Cost of Natural Gas		(27)		—
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power		9		18
Interest rate instrument	Interest Expense		(47)		—
Total			$	384	$	(59)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power		$	9	$	18
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas		$	(27)	$	—

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.

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Recurring Fair Value Measures

FAIR VALUE MEASUREMENTS (Tables)

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at March 31, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	18	$	1	$	—	$	19
Equity securities	312		4		—		316
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	24		13		—		37
Municipal bonds	—		266		—		266
Other securities	—		230		—		230
Total debt securities	24		509		—		533
Total nuclear decommissioning trusts(1)	354		514		—		868
Short-term investments held in Rabbi Trust	48		—		—		48
Interest rate instruments	—		39		—		39
Commodity contracts not subject to rate recovery	—		20		—		20
Effect of netting and allocation of collateral(2)	317		—		—		317
Commodity contracts subject to rate recovery	7		3		30		40
Effect of netting and allocation of collateral(2)	79		10		6		95
Support Agreement, net of related guarantee fees	—		—		24		24
Total	$	805	$	586	$	60	$	1,451
Liabilities:
Interest rate instruments	$	—	$	73	$	—	$	73
Foreign exchange instruments	—		13		—		13
Commodity contracts not subject to rate recovery	—		16		—		16
Commodity contracts subject to rate recovery	—		40		—		40
Total	$	—	$	142	$	—	$	142

(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 March 31, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	18	$	1	$	—	$	19
Equity securities	312		4		—		316
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	24		13		—		37
Municipal bonds	—		266		—		266
Other securities	—		230		—		230
Total debt securities	24		509		—		533
Total nuclear decommissioning trusts(1)	354		514		—		868
Commodity contracts subject to rate recovery	7		2		30		39
Effect of netting and allocation of collateral(2)	78		—		6		84
Total	$	439	$	516	$	36	$	991
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	2
Total	$	—	$	2	$	—	$	2

	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 March 31, 2023
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	1		10		—		11
Total	$	1	$	11	$	—	$	12
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	38	$	—	$	38
Total	$	—	$	38	$	—	$	38

	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


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)









	Three months ended March 31,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized (losses) gains	(4)		7
Settlements	(1)		(3)
Balance at March 31	$	30	$	58
Change in unrealized (losses) gains relating to instruments still held at March 31	$	(2)	$	9

(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 March 31,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	9		8
Settlements	(2)		(3)
Balance at March 31(2)	$	24	$	12
Change in unrealized gains relating to instruments still held at March 31	$	9	$	7

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

(2) Includes $7 in Other Current Assets and $17 in Other Long-term Assets at March 31, 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 March 31 were as follows:


LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS

Settlement year	Price per MWh					Weighted-average price per MWh
2023	$	28.55	to	$	150.00	$	82.19
2022		26.55	to		137.80		62.79

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

3 Months Ended

Mar. 31, 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
	March 31, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	37	$	1	$	(1)	$	37
Municipal bonds(2)	274		2		(10)		266
Other securities(3)	245		2		(17)		230
Total debt securities	556		5		(28)		533
Equity securities	112		209		(5)		316
Short-term investments, primarily cash equivalents	19		—		—		19
Receivables (payables), net	(4)		—		—		(4)
Total	$	683	$	214	$	(33)	$	864

	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 2023-2056.

(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 March 31,
		2023		2022
Proceeds from sales		$	156	$	242
Gross realized gains		2		11
Gross realized losses		(3)		(4)

COMMITMENTS AND CONTINGENCIES (Tables)

3 Months Ended

Mar. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Schedule of Operating Lease Payments Received, Lease Income Table

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


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended March 31,
		2023		2022
Sales-type leases:

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

Operating leases:
Fixed lease payments		$	80	$	70
Variable lease payments		2		1
Total revenues from operating leases(1)		$	82	$	71

Depreciation expense		$	15	$	13

(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 March 31,
		2023		2022
Sales-type leases:

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

Operating leases:
Fixed lease payments		$	80	$	70
Variable lease payments		2		1
Total revenues from operating leases(1)		$	82	$	71

Depreciation expense		$	15	$	13

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

SEGMENT INFORMATION (Tables)

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Segment Information


SEGMENT INFORMATION
(Dollars in millions)
	Three months ended March 31,
		2023		2022
REVENUES
SDG&E		$	1,653	$	1,445
SoCalGas		3,794		1,993
Sempra Infrastructure		1,196		424
Adjustments and eliminations		1		2
Intersegment revenues(1)		(84)		(44)
Total		$	6,560	$	3,820
DEPRECIATION AND AMORTIZATION
SDG&E		$	262	$	239
SoCalGas		206		187
Sempra Infrastructure		69		65
All other		2		2
Total		$	539	$	493
INTEREST INCOME
SDG&E		$	1	$	—
SoCalGas		4		—
Sempra Infrastructure		15		21
All other		4		4
Total		$	24	$	25
INTEREST EXPENSE
SDG&E		$	118	$	106
SoCalGas		69		40
Sempra Infrastructure		95		27
All other		84		70
Total		$	366	$	243
INCOME TAX EXPENSE (BENEFIT)
SDG&E		$	7	$	64
SoCalGas		94		84

Sempra Infrastructure		330		91
All other		(55)		95
Total		$	376	$	334
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities		$	1	$	2
Sempra Infrastructure		131		141

		132		143
Equity earnings, net of income tax:
Sempra Texas Utilities		83		162
Sempra Infrastructure		4		21
		87		183
Total		$	219	$	326


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended March 31,
		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E		$	258	$	234
SoCalGas		360		334
Sempra Texas Utilities		83		162
Sempra Infrastructure		315		95
All other		(47)		(213)
Total		$	969	$	612
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	624	$	552
SoCalGas		458		468
Sempra Infrastructure		744		182
All other		4		2
Total		$	1,830	$	1,204

		March 31, 2023		December 31, 2022
ASSETS
SDG&E		$	27,188	$	26,422
SoCalGas		22,776		22,346
Sempra Texas Utilities		13,852		13,781
Sempra Infrastructure		16,547		15,760
All other		1,282		1,376
Intersegment receivables		(1,096)		(1,111)
Total		$	80,549	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities		$	13,843	$	13,772
Sempra Infrastructure		1,893		1,905
Total		$	15,736	$	15,677

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	3 Months Ended
	Mar. 31, 2023 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

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

Mar. 31, 2023

Dec. 31, 2022

Mar. 31, 2022

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Restricted cash, noncurrent

$ 534

$ 370

^[1]

Restricted cash, current

^[1]

^[1]

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

$ 703

$ 462

$ 2,536

$ 581

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022	Dec. 31, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 2,443		$ 2,334
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	181	$ 136
Provisions for expected credit losses	117	48
Write-offs	(20)	(19)
Ending balance	278	165
Allowance for credit losses	6		7
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	238		140
Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	12		25
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	40		40
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	4		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	879		819
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	78	66
Provisions for expected credit losses	38	21
Write-offs	(11)	(9)
Ending balance	105	78
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	80		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	11		12
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	25		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	3		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	1,424		1,311
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	98	69
Provisions for expected credit losses	77	26
Write-offs	(9)	(10)
Ending balance	166	$ 85
Southern California Gas Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	151		83
Southern California Gas Company \| Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	1		13
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	15		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
Customers Under California Arrearage Payment Program \| San Diego Gas and Electric Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			51	$ 63
Customers Under California Arrearage Payment Program \| Southern California Gas Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			$ 59	$ 79

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

Mar. 31, 2023

Dec. 31, 2022

Inventory [Line Items]

Natural gas

$ 41

$ 106

LNG

Materials and supplies

267

235

Total

315

403

^[1]

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

142

133

Total

143

134

^[1]

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

106

Total

$ 130

$ 159

^[1]

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 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	$ 320	$ 316

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 73	$ 57
San Diego Gas and Electric Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	31	28
Southern California Gas Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 15	$ 18

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

3 Months Ended

Mar. 31, 2023

Dec. 31, 2022

Property plant and equipment, net

$ 49,805

$ 47,782

^[1]

Finance lease obligations

1,346

1,343

Equity method investment

13,735

13,665

^[1]

Oncor Holdings | Sempra Texas Utilities

80,549

78,574

^[1]

Cameron LNG Holdings | Sempra Infrastructure

Equity method investment

13,735

13,665

Equity method investment

880

886

Property plant and equipment, net

22,192

21,806

^[1]

Finance lease obligations

1,249

1,256

$ 27,188

26,422

^[1]

IEnova | ECA LNG JV

Ownership percentage in consolidated entity

83.40%

Subsidiary of TOTAL SE | ECA LNG JV

Ownership percentage in consolidated entity

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

1,188

1,194

Finance lease obligations

1,188

1,194

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

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

1,199

1,099

Liabilities

778

$ 685

Organization, Consolidation and Presentation of Financial Statements [Abstract]

1,901

Liabilities

$ 913

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 28	$ 41
Interest cost	40	30
Expected return on assets	(43)	(46)
Amortization of:
Prior service cost (credit)	1	3
Actuarial loss (gain)	2	6
Net periodic benefit cost (credit)	28	34
Regulatory adjustments	29	(27)
Total expense recognized	57	7
Pension \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	8	10
Interest cost	10	7
Expected return on assets	(10)	(11)
Amortization of:
Actuarial loss (gain)	1	0
Net periodic benefit cost (credit)	9	6
Regulatory adjustments	4	(5)
Total expense recognized	13	1
Pension \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	17	28
Interest cost	25	20
Expected return on assets	(29)	(31)
Amortization of:
Prior service cost (credit)	1	2
Actuarial loss (gain)	0	4
Net periodic benefit cost (credit)	14	23
Regulatory adjustments	25	(22)
Total expense recognized	39	1
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	7
Interest cost	9	7
Expected return on assets	(17)	(16)
Amortization of:
Prior service cost (credit)	(1)	(1)
Actuarial loss (gain)	(6)	(4)
Net periodic benefit cost (credit)	(11)	(7)
Regulatory adjustments	11	7
Total expense recognized	0	0
PBOP \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	2
Interest cost	2	1
Expected return on assets	(2)	(2)
Amortization of:
Actuarial loss (gain)	(1)	(1)
Net periodic benefit cost (credit)	0	0
Regulatory adjustments	0	0
Total expense recognized	0	0
PBOP \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	5
Interest cost	7	5
Expected return on assets	(15)	(13)
Amortization of:
Prior service cost (credit)	(1)	(1)
Actuarial loss (gain)	(5)	(3)
Net periodic benefit cost (credit)	(11)	(7)
Regulatory adjustments	11	7
Total expense recognized	$ 0	$ 0

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

Mar. 31, 2023

Dec. 31, 2022

Dedicated assets in support of certain benefit plans

$ 511

$ 505

^[1]

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended
	Jan. 31, 2023	Mar. 31, 2023	Mar. 31, 2022
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares		$ 969	$ 612
Earnings attributable to common shares		$ 969	$ 612
Weighted-average common shares outstanding for basic EPS (in shares)		314,919,000	316,353,000
Dilutive effect of stock options and RSUs (in shares)		1,205,000	1,081,000
Weighted-average common shares outstanding for diluted EPS (in shares)		316,124,000	317,434,000
Earnings per share, basic (dollars per share)		$ 3.08	$ 1.93
Earnings per share, diluted (in dollars per share)		$ 3.07	$ 1.93
Vested RSUs included in basic WASO (in shares)		360,000	407,000
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)	325,412
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)	130,319
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)		180,015	337,239

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

3 Months Ended

Mar. 31, 2023

Mar. 31, 2022

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

^[1]

$ 27,115

(43)

$ 83

(4)

(47)

Total accumulated other comprehensive income (loss)

27,667

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

(135)

(318)

Foreign currency translation adjustments

(182)

(229)

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

(59)

(79)

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

(49)

(76)

Financial instruments

(156)

(40)

(5)

(45)

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

(35)

(78)

Pension and PBOP

(86)

(83)

(13)

(12)

(98)

(75)

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)

9,325

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

(7)

(10)

San Diego Gas and Electric Company | Pension and PBOP

(7)

(10)

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

(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)

7,059

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

(24)

(31)

Southern California Gas Company | Financial instruments

(23)

(30)

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

(12)

(13)

Southern California Gas Company | Pension and PBOP

(12)

(13)

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

(12)

(18)

$ (11)

$ (17)

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance	$ 1,209	$ 1,086
Interest expense	(366)	(243)
Equity earnings	219	326
Energy-related businesses	1,121	383
Other Income, Net	41	38
Income before income taxes and equity earnings	1,329	665
Income tax expense	(376)	(334)
Net income	1,172	657
Earnings Attributable to Noncontrolling Interests	(192)	(34)
San Diego Gas and Electric Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(118)	(106)
Other Income, Net	28	34
Income before income taxes and equity earnings	265	298
Income tax expense	(7)	(64)
Net income	258	234
Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(69)	(40)
Other Income, Net	(8)	34
Income before income taxes and equity earnings	454	418
Income tax expense	(94)	(84)
Net income	360	334
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	(4)	6
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
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	(11)	5
Income tax expense	3	(1)
Net income	(8)	4
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	0	(1)
Equity earnings	(7)	14
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	1	(1)
Energy-related businesses	0	(1)
Other Income, Net	1	0
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)
Reclassification out of Accumulated Other Comprehensive Income \| Gains (Losses) on Cash Flow hedges Attributable to Noncontrolling Interests
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings Attributable to Noncontrolling Interests	3	0
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	0	2
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]
Other Income, Net		1
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	1	1
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
Income tax expense	0	(1)
Net income	1	2
Reclassification out of Accumulated Other Comprehensive Income \| Pension and PBOP \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost		0
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	$ (5)	$ 4

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

3 Months Ended

Mar. 20, 2023

Jan. 11, 2022

Mar. 31, 2023

Mar. 31, 2022

Dec. 31, 2022

Increase in shareholders' equity

$ 2,558

$ 2,121

^[1]

Increase in equity

$ 6

$ 255

Port Arthur LNG

Indirect Subsidiary Of SI Partners | Port Arthur LNG

Increase in equity

$ 237

Increase in shareholders' equity

Cash consideration

265

Sale of noncontrolling interest, transaction costs

Sale of noncontrolling interest, tax impacts

$ 7

Port Arthur LNG | Indirect Subsidiary Of SI Partners

Funding commitment, aggregate amount

30.00%

Funding commitment

110.00%

$ 9,000

Guaranteed funding amount

70.00%

Port Arthur LNG | Minimum | KKR Denali

Port Arthur LNG | Maximum | KKR Denali

14.90%

SI Partners | Sempra Infrastructure

31.50%

30.00%

$ 2,198

$ 2,060

SI Partners | KKR Denali

Ownership percentage, minimum indirect interest transferred

25.00%

Ownership percentage, maximum indirect interest transferred

48.65%

Cash consideration for minimum amount of interest transferred

$ 64

Cash consideration for maximum amount of interest transferred

125

Share of development costs incurred, threshold

439

Termination fee

$ 130

SI Partners subsidiaries | Sempra Infrastructure

SI Partners subsidiaries | Minimum | Sempra Infrastructure

$ 360

$ 61

SI Partners subsidiaries | Maximum | Sempra Infrastructure

0.10%

30.00%

16.60%

Accelerated share repurchase program, prepaid amount

$ 200

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

1,472,756

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

$ 135.80

[1]	Derived from audited financial statements.

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

3 Months Ended

12 Months Ended

Mar. 31, 2023

Dec. 31, 2022

$ 74

$ 54

^[1]

(278)

(301)

^[1]

Maximum borrowing capacity

(41)

^[1]

9,900

Tax Sharing Arrangement

Various affiliates

TAG Pipeline Norte

(41)

Maximum borrowing capacity

(143)

(135)

^[1]

1,500

San Diego Gas and Electric Company | Various affiliates

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

(16)

(14)

Income taxes due from Sempra Energy

(52)

(49)

(8)

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

(75)

(72)

^[1]

Maximum borrowing capacity

(36)

^[1]

1,200

Southern California Gas Company | Various affiliates

Southern California Gas Company | Due to/from Sempra Energy

Income taxes due from Sempra Energy

(36)

(25)

(16)

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

Sempra Infrastructure

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

$ (278)

(301)

5.50%

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

$ 0

(40)

5.50%

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

$ (23)

(23)

5.50%

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

$ (21)

(21)

5.50%

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

$ (19)

(19)

5.50%

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

$ (11)

(11)

5.50%

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

$ (14)

5.74%

$ (190)

$ (187)

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Related Party Transaction [Line Items]
Revenue from related parties	$ 13	$ 7
Interest income	0	10
Interest expense	4	4
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Revenue from related parties	4	4
Costs of sales to related parties	30	24
Southern California Gas Company
Related Party Transaction [Line Items]
Revenue from related parties	34	26
Costs of sales to related parties	$ 31	$ 0

Amount of revenue, fees and commissions earned from transactions between (a) a parent company and its subsidiaries; (b) subsidiaries of a common parent; (c) an entity and trusts for the benefit of employees, for example, but not limited to, pension and profit-sharing trusts that are managed by or under the trusteeship of the entity's management; (d) an entity and its principal, owners, management, or members of their immediate families; and (e) affiliates.

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-URI https://asc.fasb.org/extlink&oid=126953954&loc=SL114868664-224227

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME, NET (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Other Income [Line Items]
Allowance for equity funds used during construction	$ 33	$ 35
Investment (losses) gains, net	12	(13)
Gains on interest rate and foreign exchange instruments, net	5	6
Foreign currency transaction (losses) gains, net	1	(19)
Non-service components of net periodic benefit cost	(25)	41
Interest on regulatory balancing accounts, net	18	1
Sundry, net	(3)	(13)
Total	41	38
San Diego Gas and Electric Company
Other Income [Line Items]
Allowance for equity funds used during construction	23	21
Non-service components of net periodic benefit cost	(4)	11
Interest on regulatory balancing accounts, net	10	1
Sundry, net	(1)	1
Total	28	34
Southern California Gas Company
Other Income [Line Items]
Allowance for equity funds used during construction	10	13
Non-service components of net periodic benefit cost	(19)	32
Interest on regulatory balancing accounts, net	8	0
Sundry, net	(7)	(11)
Total	$ (8)	34
IMG
Other Income [Line Items]
Foreign currency transaction (losses) gains, net		$ (11)

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 376	$ 334
Income before income taxes and equity earnings	1,329	665
Equity earnings, before income tax:	132	143
Pretax income	$ 1,461	$ 808
Effective income tax rate (as a percent)	26.00%	41.00%
Deferred income tax liability for foreign earnings		$ 120
San Diego Gas and Electric Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 7	64
Income before income taxes and equity earnings	$ 265	$ 298
Effective income tax rate (as a percent)	3.00%	21.00%
Southern California Gas Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 94	$ 84
Income before income taxes and equity earnings	$ 454	$ 418
Effective income tax rate (as a percent)	21.00%	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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Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

+ References + Details

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 5,889	$ 3,689
Utilities regulatory revenues	(159)	25
Other revenues	830	106
Total revenues	6,560	3,820
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,598	3,412
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	291	277
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,564	2,445
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,325	1,244
Operating Segments \| San Diego Gas and Electric Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,765	1,501
Utilities regulatory revenues	(112)	(56)
Other revenues	0	0
Total revenues	1,653	1,445
Operating Segments \| San Diego Gas and Electric Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,765	1,501
Operating Segments \| San Diego Gas and Electric Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments \| San Diego Gas and Electric Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	554	330
Operating Segments \| San Diego Gas and Electric Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,211	1,171
Operating Segments \| Southern California Gas Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,841	1,912
Utilities regulatory revenues	(47)	81
Other revenues	0	0
Total revenues	3,794	1,993
Operating Segments \| Southern California Gas Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,841	1,912
Operating Segments \| Southern California Gas Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments \| Southern California Gas Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,841	1,912
Operating Segments \| Southern California Gas Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Operating Segments \| Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	342	320
Utilities regulatory revenues	0	0
Other revenues	854	104
Total revenues	1,196	424
Operating Segments \| Sempra Infrastructure \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	30	28
Operating Segments \| Sempra Infrastructure \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	312	292
Operating Segments \| Sempra Infrastructure \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	204	229
Operating Segments \| Sempra Infrastructure \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	138	91
Consolidation, Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(59)	(44)
Utilities regulatory revenues	0	0
Other revenues	(24)	2
Total revenues	(83)	(42)
Consolidation, Eliminations \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(38)	(29)
Consolidation, Eliminations \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(21)	(15)
Consolidation, Eliminations \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(35)	(26)
Consolidation, Eliminations \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (24)	$ (18)

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (252)	$ (278)
Revenue from performance obligations satisfied during reporting period	2	39
Contract liabilities, closing balance	(250)	(239)
Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(12)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(238)
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	1	1
Contract liabilities, closing balance	(78)	$ (82)
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	$ (74)

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 2,443	$ 2,334
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2,417	2,291
Accounts receivable – trade, net \| Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	81	72
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	12	25
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	10	9
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	4	9
San Diego Gas and Electric Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	879	819
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	859	799
San Diego Gas and Electric Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	11	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	3	6
Southern California Gas Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,424	1,311
Southern California Gas Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,422	1,295
Southern California Gas Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1	13
Southern California Gas Company \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1	$ 3

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (785)	$ (906)
San Diego Gas and Electric Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	648	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)	(28)	(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)	372	296
San Diego Gas and Electric Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	7	11
San Diego Gas and Electric Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,319)	(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)	124	123
San Diego Gas and Electric Company \| Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	184	220
San Diego Gas and Electric Company \| Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	30	60
San Diego Gas and Electric Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	135	107
San Diego Gas and Electric Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(100)	(69)
San Diego Gas and Electric Company \| Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	443	375
San Diego Gas and Electric Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	100	99
San Diego Gas and Electric Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(169)	(50)
San Diego Gas and Electric Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	154	137
San Diego Gas and Electric Company \| Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(961)	(942)
Southern California Gas Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	754	692
Southern California Gas Company \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	208	161
Southern California Gas Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(201)	(170)
Southern California Gas Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(610)	(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)	38	38
Southern California Gas Company \| Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(376)	(257)
Southern California Gas Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	595	575
Southern California Gas Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(132)	(158)
Southern California Gas Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	24	23
Southern California Gas Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	267	115
Southern California Gas Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	261	223
Southern California Gas Company \| Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	98	(42)
Sempra Infrastructure \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 78	$ 78

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%

REGULATORY MATTERS - FERC RATE MATTERS (Details) - San Diego Gas and Electric Company	3 Months Ended
	Mar. 31, 2023
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
FERC requirement, additional basis spread	0.50%

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		3 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) projectOwner bank	Mar. 31, 2023 USD ($)	Mar. 31, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 199	$ 204
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]
Contributions to equity method investments			$ 85	85
Sempra Texas Utilities \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 85	85
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity			50.20%
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 24
Sempra Infrastructure \| Other current assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			7
Sempra Infrastructure \| Other long-term assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			17
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 114	$ 119
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

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Schedule of Equity Method Investments [Line Items]
Net income	$ 1,172	$ 657
Equity Method Investment, Nonconsolidated Investee or Group of Investees \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,292	1,249
Operating expenses	(1,024)	(897)
Operating income	268	352
Interest expense	(123)	(108)
Income tax expense	(24)	(42)
Net income	99	191
Noncontrolling interest held by Texas Transmission Investment LLC	(20)	(38)
Earnings attributable to Sempra Energy	$ 79	$ 153

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details) $ in Millions	1 Months Ended	3 Months Ended
	Mar. 31, 2023 USD ($) lender	Mar. 31, 2023 USD ($) lineOfCredit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900	$ 9,900
Primary committed lines of credit \| lineOfCredit		8
Line of credit outstanding	(1,284)	$ (1,284)
Available unused credit	7,686	7,686
Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(930)	(930)
Sempra Energy
Line of Credit Facility [Line Items]
Maximum borrowing capacity	4,000	4,000
Line of credit outstanding	0	0
Available unused credit	3,293	3,293
Sempra Energy \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(707)	(707)
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500	1,500
Line of credit outstanding	0	0
Available unused credit	1,500	1,500
San Diego Gas and Electric Company \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	0	0
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,200	1,200
Line of credit outstanding	0	0
Available unused credit	977	977
Southern California Gas Company \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(223)	(223)
SI Partners
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,000	1,000
Line of credit outstanding	0	0
Available unused credit	$ 1,000	$ 1,000
Maximum adjustment EBITDA allowed	5.25	5.25
SI Partners \| Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	$ 0	$ 0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due September 2023
Line of Credit Facility [Line Items]
Maximum borrowing capacity	350	350
Line of credit outstanding	(350)	(350)
Available unused credit	0	0
IEnova And SI Partners \| IEnova Committed Line Of Credit Due December 2023
Line of Credit Facility [Line Items]
Maximum borrowing capacity	150	150
Line of credit outstanding	(8)	(8)
Available unused credit	142	142
IEnova And SI Partners \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500	1,500
Line of credit outstanding	(926)	(926)
Available unused credit	574	574
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	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	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	0
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	200	200
Line of credit outstanding	0	0
Available unused credit	200	200
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	0
Port Arthur LNG \| Line of Credit \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 200	$ 200
Term of debt instrument	7 years
Number of lenders \| lender	4
Sempra U.S.
Line of Credit Facility [Line Items]
Maximum ratio of indebtedness to total capitalization (as a percent)	65.00%	65.00%

DEBT AND CREDIT FACILITIES - UNCOMMITTED LINE OF CREDIT (Details)	3 Months Ended
	Mar. 31, 2023 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900,000,000
IEnova Committed Line Of Credit Due 2024 \| IEnova And SI Partners
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,500,000,000
IEnova Committed Line Of Credit Due 2024 \| Interbank Equilibrium Interest Rate \| IEnova And SI Partners
Line of Credit Facility [Line Items]
Variable percentage rate	1.05%
IEnova Committed Line Of Credit Due 2024 \| LIBOR \| IEnova And SI Partners
Line of Credit Facility [Line Items]
Variable percentage rate	1.05%
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 200,000,000
Amount available	$ 25,000,000

Segment Reporting Information [Line Items]

The carrying value as of the balance sheet date of the current portion of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

+ References + Details

DEBT AND CREDIT FACILITIES - UNCOMMITTED LETTERS OF CREDIT (Details) $ in Millions	Mar. 31, 2023 USD ($)
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 533
Letter of Credit
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	533
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	330
Letter of Credit \| Parent and Other
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 168

DEBT AND CREDIT FACILITIES - TERM LOAN (Details) - USD ($)	1 Months Ended		3 Months Ended
	Aug. 31, 2022	Jul. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Short-Term Debt [Line Items]
Proceeds from borrowings			$ 1,986,000,000	$ 4,023,000,000
Southern California Gas Company
Short-Term Debt [Line Items]
Proceeds from borrowings			$ 0	$ 697,000,000
Term Loan Due 2023 \| Southern California Gas Company
Short-Term Debt [Line Items]
Proceeds from borrowings	$ 800,000,000
Term Loan Due 2023 \| Secured Debt \| Southern California Gas Company
Short-Term Debt [Line Items]
Debt amount		$ 800,000,000
Term of debt instrument		364 days
Spread on variable rate (as a percent)		0.70%

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Mar. 31, 2023	Dec. 31, 2022
Sempra
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.68%	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	5.37%	4.71%

DEBT AND CREDIT FACILITIES - LONG-TERM DEBT (Details) - Five Point Three Five Zero Percent Senior Secured Notes - Secured Debt - San Diego Gas and Electric Company $ in Millions	1 Months Ended
	Mar. 31, 2023 USD ($)
Debt Instrument [Line Items]
Debt amount	$ 800
Stated rate of debt (as a percent)	5.35%
Proceeds from debt issuance	$ 783
Unamortized debt issuance costs	$ 17

DEBT AND CREDIT FACILITIES - SEMPRA INFRASTRUCTURE (Details)			3 Months Ended
	Mar. 21, 2023 USD ($)	Mar. 20, 2023 USD ($) lender	Mar. 31, 2023 USD ($) bank	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 9,900,000,000
IEnova \| ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity			83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity			16.60%
SI Partners
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 1,000,000,000
Loan Agreement To Finance Natural Gas Liquefaction Export Facility \| Sempra LNG
Debt Instrument [Line Items]
Term of debt instrument			5 years
Number of banks in syndicate \| bank			7
Weighted average interest rate (as a percent)			7.86%	7.54%
Loan Agreement To Finance Natural Gas Liquefaction Export Facility \| Sempra Infrastructure
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 1,300,000,000
Debt outstanding			634,000,000	$ 575,000,000
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| SI Partners and ConocoPhillips
Debt Instrument [Line Items]
Equity funding provided		$ 2,800,000,000
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| SI Partners \| Port Arthur LNG
Debt Instrument [Line Items]
Ownership interest (as a percent)		70.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| ConocoPhillips \| Port Arthur LNG
Debt Instrument [Line Items]
Ownership interest (as a percent)		30.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Port Arthur LNG
Debt Instrument [Line Items]
Term of debt instrument		20 years
Number of banks in syndicate \| lender		21
Debt outstanding			$ 215,000,000
Weighted average interest rate (as a percent)			5.44%
Debt amount			$ 6,800,000,000
Upfront equity funding amount	$ 4,700,000,000
Debt issuance costs	$ 200,000,000
Commitment fee	30.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Port Arthur LNG \| Secured Overnight Financing Rate (SOFR)
Debt Instrument [Line Items]
Minimum amount of the projected amount of term loans		60.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Port Arthur LNG \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, Before Completion of Phase 1
Debt Instrument [Line Items]
Variable percentage rate		2.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Loans Payable \| Port Arthur LNG \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, After Completion of Phase 1
Debt Instrument [Line Items]
Variable percentage rate		2.25%

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2023 MMBTU MWh	Dec. 31, 2022 MMBTU MWh
Natural gas \| Long
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	355	254
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	40	42
SDG&E \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	16	15
SDG&E \| Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	40	42
SoCalGas \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	248	224

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES (Details) $ in Millions		3 Months Ended
	Mar. 20, 2023 USD ($)	Mar. 31, 2023 USD ($)	Mar. 31, 2022 USD ($)	Mar. 21, 2023 USD ($) counterparty	Dec. 31, 2022 USD ($)
Derivative [Line Items]
Cash paid to settle		$ 99	$ 0
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Derivative [Line Items]
Minimum amount of the projected amount of term loans	60.00%
Interest Rate Swap \| Cash Flow Hedging
Derivative [Line Items]
Amount of interest rate swap					$ 3,500
Interest rate swap tenor		25 years
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG
Derivative [Line Items]
Cash paid to settle	$ 14
Number of counterparties \| counterparty				17
Notional amounts				$ 200
Fixed rate		3.23%
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG \| Maximum
Derivative [Line Items]
Notional amounts		$ 4,200

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Mar. 31, 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	88	111
Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Notional amount of derivative	$ 4,457	$ 294

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ (95)	$ 98
Pretax gain (loss) on derivatives recognized in earnings	$ 5	$ 6
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 (loss) gain recognized in OCI	$ (98)	$ 120
Pretax gain (loss) reclassified from AOCI into earnings	11	(5)
Derivatives designated as hedging instruments \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(77)	22
Pretax gain (loss) reclassified from AOCI into earnings	0	1
Derivatives designated as hedging instruments \| Equity Earnings \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(17)	94
Pretax gain (loss) reclassified from AOCI into earnings	7	(14)
Derivatives designated as hedging instruments \| Equity Earnings \| Cash Flow Hedging \| Foreign Exchange Instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(5)	(2)
Pretax gain (loss) reclassified from AOCI into earnings	(1)	1
Derivatives designated as hedging instruments \| Revenues: Energy- Related Businesses \| Cash Flow Hedging \| Foreign Exchange Instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(6)	(3)
Pretax gain (loss) reclassified from AOCI into earnings	0	1
Derivatives designated as hedging instruments \| Other Income, Net \| Cash Flow Hedging \| Foreign Exchange Instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	(1)	0
Derivatives designated as hedging instruments \| Other Income, Net \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	7	9
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	384	(59)
Derivatives not designated as hedging instruments \| Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	449	(77)
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	(27)	0
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	9	18
Derivatives not designated as hedging instruments \| Contingent Interest Rate Derivative
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(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	9	18
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	$ (27)	$ 0

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 33
Cash flow hedge gain (loss) to be reclassified, NCI	$ 19
Term of interest rate cash flow hedge	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	17 years

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Derivative fair value	$ 42	$ 106
Collateral	42
Southern California Gas Company
Derivative [Line Items]
Derivative fair value	38	$ 69
Collateral	$ 38

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) $ / MWh	Mar. 31, 2022 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 35	$ 54
Realized and unrealized (losses) gains	(4)	7
Settlements	(1)	(3)
Ending balance	30	58
Change in unrealized (losses) gains relating to instruments still held at March 31	(2)	9
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	17	7
Realized and unrealized gains	9	8
Settlements	(2)	(3)
Ending balance	24	12
Change in unrealized gains (losses) relating to instruments still held at the end of the period	9	7
Sempra Infrastructure \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7
Sempra Infrastructure \| Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	17
San Diego Gas and Electric Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	35	54
Realized and unrealized (losses) gains	(4)	7
Settlements	(1)	(3)
Ending balance	30	58
Change in unrealized (losses) gains relating to instruments still held at March 31	$ (2)	$ 9
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	28.55	26.55
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	150.00	137.80
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	82.19	62.79

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Mar. 31, 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	306	289
Finance lease obligations	1,346	1,343
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	322	318
Long-term amounts due to unconsolidated affiliate	319	301
Total long-term debt	25,386	24,513
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	313	286
Long-term amounts due to unconsolidated affiliate	284	263
Total long-term debt	22,939	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 affiliate	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 affiliate	284	263
Total long-term debt	22,939	21,549
Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	313	286
Long-term amounts due to unconsolidated affiliate	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	86	70
Finance lease obligations	1,249	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	7,747	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	7,747	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	46	48
Finance lease obligations	97	87
Southern California Gas Company \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,059	6,059
Southern California Gas Company \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,673	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	5,673	5,538
Southern California Gas Company \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

SAN ONOFRE NUCLEAR GENERATING STATION (Details) - San Diego Gas and Electric Company - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 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	$ 535
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 81

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Cost	$ 683		$ 689
Gross unrealized gains	214		196
Gross unrealized losses	(33)		(44)
Estimated fair value	864		841
Proceeds from sales	156	$ 242
Gross realized gains	2	11
Gross realized losses	(3)	$ (4)
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	556		571
Gross unrealized gains	5		2
Gross unrealized losses	(28)		(36)
Estimated fair value	533		537
U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	37		40
Gross unrealized gains	1		1
Gross unrealized losses	(1)		(1)
Estimated fair value	37		40
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	274		283
Gross unrealized gains	2		1
Gross unrealized losses	(10)		(14)
Estimated fair value	266		270
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	245		248
Gross unrealized gains	2		0
Gross unrealized losses	(17)		(21)
Estimated fair value	230		227
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	112		111
Gross unrealized gains	209		194
Gross unrealized losses	(5)		(8)
Estimated fair value	316		297
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	19		11
Gross unrealized gains	0		0
Gross unrealized losses	0		0
Estimated fair value	19		11
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(4)		(4)
Gross unrealized gains	0		0
Gross unrealized losses	0		0
Estimated fair value	$ (4)		$ (4)

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions	1 Months Ended	3 Months Ended		7 Months Ended	12 Months Ended
	Sep. 30, 2021 USD ($) lawsuit plaintiff	Mar. 31, 2023 USD ($) lawsuit	Mar. 31, 2022 USD ($)	Apr. 28, 2023 plaintiff complaint	Dec. 31, 2022 USD ($)	Feb. 21, 2023 plaintiff	Jan. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Liability for legal proceedings		$ 280
Aliso Canyon litigation and regulatory matters		0	$ 92
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings		129
Southern California Gas Company
Loss Contingencies [Line Items]
Liability for legal proceedings		204
Aliso Canyon litigation and regulatory matters		0	92
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings		129
Number of lawsuits \| lawsuit	390
Number of plaintiffs \| plaintiff	36,000
Reserve for Aliso Canyon costs		129
Net book value of Aliso Canyon facility		$ 965
Aliso Canyon litigation and regulatory matters, net of tax			$ 66
Southern California Gas Company \| Shareholder Derivative Complaint
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit		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					99.00%
Number of plaintiffs not contacted \| plaintiff						265
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				310
Loss Contingency, Number Of Complaints On Behalf Of Plaintiffs \| complaint				25
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		$ 3

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	1 Months Ended		3 Months Ended
	Oct. 31, 2020 GBP (£)	Mar. 31, 2020 GBP (£)	Mar. 31, 2023 USD ($)	Apr. 28, 2023 lawsuit claim
Plaintiffs \| HMRC VAT Claim
Loss Contingencies [Line Items]
Damages awarded		£ 45	$ 55
Cost and interest assessed	£ 21		$ 26
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 (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) agreement	Mar. 31, 2022 USD ($)
Lessee, Lease, Description [Line Items]
Interest income	$ 2	$ 2
Total revenues from sales-type leases(1)	2	2
Fixed lease payments	80	70
Variable lease payments	2	1
Total revenues from operating leases	82	71
Depreciation expense	$ 15	$ 13
San Diego Gas and Electric Company
Lessee, Lease, Description [Line Items]
Number of energy storage agreements \| agreement	5
Lease not yet commenced, remainder of year	$ 11
Lease not yet commenced, year one	45
Lease not yet commenced, year two	54
Lease not yet commenced, year three	54
Lease not yet commenced, year four	54
Lease not yet commenced, thereafter	447
Southern California Gas Company
Lessee, Lease, Description [Line Items]
Finance lease not yet commenced, remainder of fiscal year	1
Finance lease not yet commenced, year one	1
Finance lease not yet commenced, year two	1
Finance lease not yet commenced, year three	1
Finance lease not yet commenced, year four	1
Finance lease not yet commenced, year thereafter	$ 6

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) $ in Millions	3 Months Ended
	Mar. 31, 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	$ 52
Sempra Infrastructure \| Natural Gas Storage and Transportation Contracts
Loss Contingencies [Line Items]
Change since 2022	321
Change in 2023	(35)
Change in 2024	2
Change thereafter	354
Sempra Infrastructure \| Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Change in 2023	(660)
Change in 2024	40
Change in 2025	78
Change in 2026	62
Change in 2027	44
Change thereafter	36
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	18
Southern California Gas Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	$ 20

SEGMENT INFORMATION (Details)
$ in Millions

3 Months Ended

Mar. 31, 2023

USD ($)

segment

Mar. 31, 2022

USD ($)

Dec. 31, 2022

USD ($)

Number of reportable segments | segment

Segment Reporting Information, Profit (Loss) [Abstract]

$ 6,560

$ 3,820

539

493

366

243

Equity earnings, before income tax:

376

334

132

143

Equity earnings, net of income tax:

183

Equity earnings

219

326

Segment Reporting Information, Additional Information [Abstract]

969

612

1,830

1,204

EQUITY METHOD INVESTMENTS

80,549

$ 78,574

^[1]

15,736

15,677

Operating Segments | SDG&E

Segment Reporting Information, Profit (Loss) [Abstract]

1,653

1,445

262

239

118

106

Segment Reporting Information, Additional Information [Abstract]

258

234

624

552

Operating Segments | SoCalGas

27,188

26,422

Segment Reporting Information, Profit (Loss) [Abstract]

3,794

1,993

206

187

Segment Reporting Information, Additional Information [Abstract]

360

334

458

468

Operating Segments | Sempra Texas Utilities

22,776

22,346

Segment Reporting Information, Profit (Loss) [Abstract]

Equity earnings, before income tax:

Equity earnings, net of income tax:

162

Segment Reporting Information, Additional Information [Abstract]

162

EQUITY METHOD INVESTMENTS

13,852

13,781

13,843

13,772

Operating Segments | Sempra Infrastructure

Segment Reporting Information, Profit (Loss) [Abstract]

1,196

424

Equity earnings, before income tax:

330

131

141

Equity earnings, net of income tax:

Segment Reporting Information, Additional Information [Abstract]

315

744

182

EQUITY METHOD INVESTMENTS

16,547

15,760

1,893

1,905

Adjustments and eliminations

Segment Reporting Information, Profit (Loss) [Abstract]

Segment Reporting Information, Profit (Loss) [Abstract]

All other

(55)

Segment Reporting Information, Additional Information [Abstract]

(47)

(213)

Segment Reporting Information, Profit (Loss) [Abstract]

1,282

1,376

Intersegment revenues

Segment Reporting Information, Additional Information [Abstract]

(84)

(44)

Intersegment revenues | SDG&E

(1,096)

$ (1,111)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues | SoCalGas

(4)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues | Sempra Infrastructure

(34)

(26)

Segment Reporting Information, Profit (Loss) [Abstract]