0001032208-24-000026 | 10-Q | XBRL Viewer

$ 90,473

$ 87,181

^[1]

17,214

16,510

Segment Reporting Information, Profit (Loss) [Abstract]

3,830

$ 4,282

3,011

$ 3,335

6,651

9,895

603

549

1,197

1,088

311

317

616

683

Equity earnings, before income tax:

(130)

175

551

160

153

294

285

Equity earnings, net of income tax

273

235

487

322

Equity earnings

433

388

781

607

Operating Segments | Sempra California

713

603

1,514

1,572

Segment Reporting Information, Additional Information [Abstract]

54,462

53,430

Segment Reporting Information, Profit (Loss) [Abstract]

2,212

2,200

2,625

2,700

5,766

8,115

528

476

1,049

944

209

194

414

381

(17)

127

Operating Segments | Sempra Texas Utilities

316

339

898

957

Segment Reporting Information, Additional Information [Abstract]

14,940

14,392

Segment Reporting Information, Profit (Loss) [Abstract]

14,927

14,380

Equity earnings, before income tax:

Equity earnings, net of income tax

202

160

385

243

Operating Segments | Sempra Infrastructure

202

160

385

243

Segment Reporting Information, Additional Information [Abstract]

21,131

19,430

2,286

2,129

Segment Reporting Information, Profit (Loss) [Abstract]

1,617

2,078

409

660

928

1,856

145

139

120

Equity earnings, before income tax:

(133)

201

(24)

531

158

151

290

282

Equity earnings, net of income tax

102

Segment Reporting Information, Additional Information [Abstract]

291

208

422

523

All other

963

967

Segment Reporting Information, Profit (Loss) [Abstract]

103

203

183

(41)

(9)

(61)

(64)

Adjustments and eliminations

(96)

(104)

(191)

(151)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues and eliminations

(2)

Segment Reporting Information, Additional Information [Abstract]

Segment Reporting Information, Profit (Loss) [Abstract]

(1,023)

$ (1,038)

(24)

(23)

(43)

(74)

(1)

Intersegment revenues and eliminations | Sempra California

(1)

Segment Reporting Information, Profit (Loss) [Abstract]

Intersegment revenues and eliminations | Sempra Infrastructure

Segment Reporting Information, Profit (Loss) [Abstract]

Beginning Balance at Dec. 31, 2022

$ 19

$ 33

$ 65

[1]	Derived from audited financial statements.

REGULATORY MATTERS - FERC RATE MATTERS (Details) - SDG&E	6 Months Ended
	Jun. 30, 2024
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
FERC requirement, additional basis spread	0.50%

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2024 USD ($) $ / MWh	Jun. 30, 2023 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 9	$ 30	$ 10	$ 35
Realized and unrealized gains (losses), net	(2)	(4)	(3)	(8)
Allocated transmission instruments	0	(2)	0	(2)
Settlements	(1)	(4)	(1)	(5)
Ending balance	6	20	6	20
Change in unrealized losses relating to instruments still held at June 30	(1)	(7)	(2)	(9)
Other Sempra
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	23	24	23	17
Realized and unrealized gains (losses), net	2	1	4	10
Settlements	(2)	(2)	(4)	(4)
Ending balance	23	23	23	23
Change in unrealized gains relating to instruments still held at June 30	2	1	3	9
Other Sempra \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Other Sempra \| Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	16		16
SDG&E
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	9	30	10	35
Realized and unrealized gains (losses), net	(2)	(4)	(3)	(8)
Allocated transmission instruments	0	(2)	0	(2)
Settlements	(1)	(4)	(1)	(5)
Ending balance	6	20	6	20
Change in unrealized losses relating to instruments still held at June 30	$ (1)	$ (7)	$ (2)	$ (9)
Level 3 \| SDG&E \| Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(3.69)	(3.09)
Level 3 \| SDG&E \| Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			9.55	10.71
Level 3 \| SDG&E \| Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(0.44)	(0.56)

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (311)	$ (317)	$ (616)	$ (683)
Energy-related businesses	373	621	848	1,742
Other income, net	(30)	(31)	(129)	(72)
Income before income taxes and equity earnings	308	523	1,013	1,852
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income	871	736	1,752	1,908
Earnings attributable to noncontrolling interests	(146)	(121)	(215)	(313)
Net income attributable to Sempra	725	615	1,537	1,595
SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(78)	(71)	(155)	(140)
Other income, net	(13)	(1)	(60)	7
Income before income taxes and equity earnings	141	135	543	589
Income tax benefit (expense)	(10)	21	(53)	(73)
Net income	131	156	490	516
Net income attributable to Sempra	131	156	490	516
SDG&E
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(131)	(123)	(259)	(241)
Other income, net	(23)	(22)	(56)	(50)
Income before income taxes and equity earnings	220	188	483	453
Income tax benefit (expense)	(34)	(4)	(74)	(11)
Net income	186	184	409	442
Net income attributable to Sempra	186	184	409	442
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income attributable to Sempra	(3)	(3)	(7)	(7)
Reclassification out of Accumulated Other Comprehensive Income \| SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income attributable to Sempra	1	1	2	2
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	(18)	(13)	(31)	(24)
Income tax benefit (expense)	3	0	6	3
Net income	(15)	(13)	(25)	(21)
Net income attributable to Sempra	(10)	(4)	(16)	(9)
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(3)	0	(6)	0
Equity earnings	(10)	(14)	(15)	(21)
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments \| SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	1	1	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	(2)	1	(4)	2
Energy-related businesses	(2)	0	(5)	0
Other income, net	1	(1)	1	(2)
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	0	1	0	6
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense			0	(1)
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Net, Cash Flow Hedge, Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interests	5	9	9	12
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net	(1)	(1)	(3)	(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 \| SoCalGas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net			(1)	(1)
Reclassification out of Accumulated Other Comprehensive Income \| Settlement charges
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net	(9)	0	(9)	0
Reclassification out of Accumulated Other Comprehensive Income \| Pension and PBOP
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	10	1	13	2
Income tax benefit (expense)	(3)	0	(4)	0
Net income	$ 7	$ 1	$ 9	$ 2

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

Total

Preferred stock

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

SoCalGas

Preferred stock

SoCalGas

Common stock

SoCalGas

Retained earnings

SoCalGas

Accumulated other comprehensive income (loss)

$ 29,256

$ 889

$ 12,160

$ 14,201

$ (135)

$ 6,698

$ 22

$ 2,316

$ 4,384

$ (24)

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

1,908

1,595

516

(1)

Beginning Balance at Mar. 31, 2023

31,014

889

12,044

15,024

(121)

7,215

2,316

4,899

(22)

30,245

889

12,164

14,796

(182)

7,059

2,316

4,744

(23)

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

736

615

156

117

(1)

Beginning Balance at Dec. 31, 2023

31,014

889

12,044

15,024

(121)

7,215

2,316

4,899

(22)

33,654

^[1]

889

12,204

15,732

(150)

7,410

2,316

5,095

(23)

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

1,752

1,537

490

192

(1)

Beginning Balance at Mar. 31, 2024

35,419

889

12,250

16,461

(121)

7,901

2,316

5,584

(21)

34,661

889

12,209

16,141

(104)

7,770

2,316

5,454

(22)

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

871

725

131

(17)

(1)

$ 35,419

$ 889

$ 12,250

$ 16,461

$ (121)

$ 7,901

$ 22

$ 2,316

$ 5,584

$ (21)

[1]	Derived from audited financial statements.

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.

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DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2024 MMBTU MWh	Dec. 31, 2023 MMBTU MWh
Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	491	361
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	33	36
SDG&E \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	21	17
SDG&E \| Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	33	36
SoCalGas \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	412	268

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Net income, pretax amount, attributable to parent	$ 595	$ 790	$ 1,579	$ 2,146
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income, after tax amounts, attributable to parent	725	615	1,537	1,595
Comprehensive income, pretax amount, attributable to parent	591	871	1,626	2,164
Comprehensive income, income tax (expense) benefit, attributable to parent	116	(196)	(61)	(556)
Comprehensive income	707	675	1,565	1,608
SDG&E
Net income, pretax amount, attributable to parent	220	188	483	453
Income tax benefit (expense)	(34)	(4)	(74)	(11)
Net income, after tax amounts, attributable to parent	186	184	409	442
Comprehensive income, pretax amount, attributable to parent	220	188	483	453
Comprehensive income, income tax (expense) benefit, attributable to parent	(34)	(4)	(74)	(11)
Comprehensive income	$ 186	$ 184	$ 409	$ 442

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income, attributable to parent entity. Excludes changes in equity resulting from investments by owners and distributions to owners.

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

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The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA

6 Months Ended

Jun. 30, 2024

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities, which invest in, develop and operate energy infrastructure in North America, and provide electric and gas services to customers.

Sempra has three separate reportable segments, which we describe in Note 12. In the fourth quarter of 2023, Sempra realigned its reportable segments to reflect changes in how the CODM oversees our three platforms: Sempra California, Sempra Texas Utilities and Sempra Infrastructure. Our former SDG&E and SoCalGas reportable segments were combined into one operating and reportable segment, Sempra California, which is consistent with how the CODM assesses performance due to the similarities of their operations, including geographic location and regulatory framework in California. Sempra’s historical segment disclosures have been restated to conform with the current presentation, so that all discussions reflect the revised segment information of its three reportable segments. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name.

SDG&E

SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SDG&E is a regulated public utility that provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. SDG&E has one reportable segment.

SoCalGas

SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra. SoCalGas is a regulated public natural gas distribution utility, serving customers throughout most of Southern California and part of central California. SoCalGas has one reportable segment.

BASIS OF PRESENTATION

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

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2024 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation.

All December 31, 2023 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2023 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC.

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

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

REGULATED OPERATIONS

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

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

Our Sempra Infrastructure segment includes the operating companies of our subsidiary, SI Partners, as well as certain holding companies and risk management activity. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP.

VARIABLE INTEREST ENTITIES

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

▪the purpose and design of the VIE;

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

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

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

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

SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at June 30, 2024 and December 31, 2023. PPAs and tolling agreements that relate to SDG&E’s involvement with VIEs are primarily accounted for as finance leases. The carrying amounts of the assets and liabilities under these contracts are included in PP&E, net, and finance lease liabilities with balances of $1,151 million and $1,166 million at June 30, 2024 and December 31, 2023, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Other Sempra

Oncor Holdings

Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $14,809 million and $14,266 million at June 30, 2024 and December 31, 2023, respectively.

Cameron LNG JV

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, including LNG production and operation and maintenance activities at the liquefaction facility. Therefore, we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment was $1,114 million at June 30, 2024 and $1,008 million at December 31, 2023. Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and our obligation under the SDSRA, which we discuss in Note 5.

CFIN

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

ECA LNG Phase 1

ECA LNG Phase 1 is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that ECA LNG Phase 1 will require future capital contributions or other financial support to finance the construction of the facility. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $1,680 million and $1,580 million of assets at June 30, 2024 and December 31, 2023, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $1,049 million and $1,029 million of liabilities at June 30, 2024 and December 31, 2023, respectively, consisting primarily of long-term debt attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 6, IEnova and TotalEnergies SE have provided guarantees for 83.4% and 16.6%, respectively, of the loan facility supporting construction of the liquefaction facility.

Port Arthur LNG

Port Arthur LNG is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that Port Arthur LNG will require future capital contributions or other financial support to finance the construction of the PA LNG Phase 1 project. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate Port Arthur LNG. Sempra consolidated $5,019 million and $3,927 million of assets at June 30, 2024 and December 31, 2023, respectively, consisting primarily of PP&E, net, and other long-term assets 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 $606 million and $600 million of liabilities at June 30, 2024 and December 31, 2023, respectively, consisting primarily of accounts payable and long-term debt attributable to Port Arthur LNG for which creditors do not have recourse to the general credit of Sempra.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Condensed Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Condensed Consolidated Statements of Cash Flows. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Cash and cash equivalents	$	228	$	236
Restricted cash, current	16		49
Restricted cash, noncurrent	107		104
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	351	$	389

CREDIT LOSSES

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

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

The implementation of customer assistance programs and higher 2023 winter season customer billings have resulted in certain SDG&E and SoCalGas customers exhibiting slower payment and higher levels of nonpayment than has been the case historically. In January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances until October 2026.

SDG&E and SoCalGas have regulatory mechanisms to recover credit losses and thus record changes in the allowances for credit losses related to Accounts Receivable – Trade that are probable of recovery in regulatory accounts. We discuss regulatory accounts in Note 4 below and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

Changes in allowances for credit losses for trade receivables and other receivables are as follows:


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2024		2023
Sempra:
Allowances for credit losses at January 1	$	533	$	181
Provisions for expected credit losses	94		228
Write-offs	(112)		(43)
Allowances for credit losses at June 30	$	515	$	366
SDG&E:
Allowances for credit losses at January 1	$	144	$	78
Provisions for expected credit losses	24		63
Write-offs	(42)		(23)
Allowances for credit losses at June 30	$	126	$	118
SoCalGas:
Allowances for credit losses at January 1	$	331	$	98
Provisions for expected credit losses	45		164
Write-offs	(70)		(20)
Allowances for credit losses at June 30	$	306	$	242

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


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2024		2023
Sempra:
Accounts receivable – trade, net	$	451	$	480
Accounts receivable – other, net	52		52
Other long-term assets	12		1
Total allowances for credit losses	$	515	$	533
SDG&E:
Accounts receivable – trade, net	$	96	$	116
Accounts receivable – other, net	26		27
Other long-term assets	4		1
Total allowances for credit losses	$	126	$	144
SoCalGas:
Accounts receivable – trade, net	$	272	$	306
Accounts receivable – other, net	26		25
Other long-term assets	8		—
Total allowances for credit losses	$	306	$	331

As we discuss below in “Note Receivable,” we have an interest-bearing promissory note due from KKR Pinnacle. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on this note receivable, including compounded interest and unamortized transaction costs, based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At both June 30, 2024 and December 31, 2023, $6 million of expected credit losses are included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheets.

As we discuss in Note 5, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra Infrastructure from the SDSRA. On a quarterly basis, we evaluate credit losses and record liabilities for expected credit losses on this off-balance sheet arrangement based on external credit ratings, published default rate studies and the maturity date of the arrangement. At both June 30, 2024 and December 31, 2023, $5 million of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets.

TRANSACTIONS WITH AFFILIATES

We summarize amounts due from and to unconsolidated affiliates at the Registrants in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Tax sharing arrangement with Oncor Holdings	$	—	$	25
Various affiliates	7		6
Total due from unconsolidated affiliates – current	$	7	$	31

Tax sharing arrangement with Oncor Holdings	$	(3)	$	—
TAG Pipelines – 5.5% Note due January 9, 2024(1)	—		(5)
Total due to unconsolidated affiliates – current	$	(3)	$	(5)

TAG Pipelines(1):
5.5% Note due January 14, 2025	$	—	$	(24)
5.5% Note due July 16, 2025	—		(23)
5.5% Note due January 14, 2026	(8)		(20)
5.5% Note due July 14, 2026	(12)		(11)
5.5% Note due January 19, 2027	(15)		(14)
5.5% Note due July 21, 2027	(18)		(17)
5.5% Note due January 19, 2028	(46)		—
TAG Norte – 5.74% Note due December 17, 2029(1)	(203)		(198)
Total due to unconsolidated affiliates – noncurrent	$	(302)	$	(307)
SDG&E:
SoCalGas	$	9	$	—
Total due from unconsolidated affiliates – current	$	9	$	—

Sempra	$	(27)	$	(44)
SoCalGas	—		(21)
Various affiliates	(13)		(8)
Total due to unconsolidated affiliates – current	$	(40)	$	(73)

Income taxes due from Sempra(2)	$	223	$	246
SoCalGas:
SDG&E	$	—	$	21
Various affiliates	1		1
Total due from unconsolidated affiliates – current	$	1	$	22

Sempra	$	(34)	$	(38)
SDG&E	(8)		—
Total due to unconsolidated affiliates – current	$	(42)	$	(38)

Income taxes due from Sempra(2)	$	10	$	6

(1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding and VAT payable to the Mexican government.

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

We summarize income statement information from unconsolidated affiliates in the following table.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Revenues	$	10	$	11	$	20	$	24
Interest expense	3		4		7		8
SDG&E:
Revenues	$	5	$	6	$	11	$	10
Cost of sales	35		27		75		57
SoCalGas:
Revenues	$	37	$	28	$	81	$	62
Cost of sales(1)	—		4		(3)		35

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

Guarantees

Sempra provides guarantees related to Cameron LNG JV’s SDSRA and CFIN’s Support Agreement. We discuss these guarantees in Note 5.

INVENTORIES

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023
Natural gas	$	147	$	174	$	1	$	1	$	132	$	155
LNG	8		9		—		—		—		—
Materials and supplies	312		299		158		152		128		122
Total	$	467	$	482	$	159	$	153	$	260	$	277

DEDICATED ASSETS IN SUPPORT OF CERTAIN BENEFITS PLANS

In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $547 million and $549 million at June 30, 2024 and December 31, 2023, respectively.

WILDFIRE FUND

In July 2019, the Wildfire Legislation was signed into law to address certain issues related to catastrophic wildfires in California and their impact on electric IOUs. We discuss the Wildfire Legislation further in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

SDG&E periodically evaluates the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in assumptions. In the second quarter of 2024, SDG&E revised its estimate of the period of benefit from 15 years to 25 years.

NOTE RECEIVABLE

In November 2021, Sempra loaned $300 million to KKR Pinnacle in exchange for an interest-bearing promissory note that is due in full no later than October 2029 and bears compound interest at 5% per annum, which may be paid quarterly or added to the outstanding principal at the election of KKR Pinnacle. At June 30, 2024 and December 31, 2023, Other Long-Term Assets includes $340 million and $332 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, on Sempra’s Condensed Consolidated Balance Sheets.

PROPERTY, PLANT AND EQUIPMENT

Sempra Infrastructure’s Sonora natural gas pipeline consists of two pipeline segments, the Sasabe-Puerto Libertad-Guaymas segment and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the pipeline in the Yaqui territory that has made that section inoperable since August 2017. Sempra Infrastructure and the CFE have agreed to an amendment to their transportation services agreement and to re-route the portion of the pipeline that is in the Yaqui territory, whereby the CFE would pay for the re-routing with a new tariff. This amendment will terminate if certain conditions are not met, and Sempra Infrastructure retains the right to terminate the transportation services agreement and seek to recover its reasonable and documented costs and lost profit. Sempra Infrastructure continues to acquire and pursue the necessary rights-of-way and permits for the re-routed portion of the pipeline. At June 30, 2024, Sempra Infrastructure had $406 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if Sempra Infrastructure is unable to re-route a portion of the pipeline and resume operations or if Sempra Infrastructure terminates the contract and is unable to obtain recovery.

CAPITALIZED FINANCING COSTS

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

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


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra	$	155	$	110	$	300	$	183
SDG&E	27		31		53		62
SoCalGas	26		20		50		35

COMPREHENSIVE INCOME

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


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Three months ended June 30, 2024 and 2023
Sempra:
Balance at March 31, 2024	$	(33)	$	42	$	(113)	$	(104)
OCI before reclassifications	(16)		3		(1)		(14)
Amounts reclassified from AOCI	—		(10)		7		(3)
Net OCI	(16)		(7)		6		(17)
Balance at June 30, 2024	$	(49)	$	35	$	(107)	$	(121)

Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)
OCI before reclassifications	11		53		—		64
Amounts reclassified from AOCI	—		(4)		1		(3)
Net OCI	11		49		1		61
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
SDG&E:
Balance at March 31, 2024 and June 30, 2024					$	(8)	$	(8)





Balance at March 31, 2023 and June 30, 2023					$	(7)	$	(7)
SoCalGas:
Balance at March 31, 2024			$	(11)	$	(11)	$	(22)

Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2024			$	(10)	$	(11)	$	(21)

Balance at March 31, 2023			$	(12)	$	(11)	$	(23)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

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


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Six months ended June 30, 2024 and 2023
Sempra:
Balance at December 31, 2023	$	(36)	$	3	$	(117)	$	(150)
OCI before reclassifications	(13)		48		1		36
Amounts reclassified from AOCI	—		(16)		9		(7)
Net OCI	(13)		32		10		29
Balance at June 30, 2024	$	(49)	$	35	$	(107)	$	(121)

Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	21		13		(13)		21
Amounts reclassified from AOCI	—		(9)		2		(7)
Net OCI	21		4		(11)		14
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
SDG&E:
Balance at December 31, 2023 and June 30, 2024					$	(8)	$	(8)





Balance at December 31, 2022 and June 30, 2023					$	(7)	$	(7)
SoCalGas:
Balance at December 31, 2023			$	(11)	$	(12)	$	(23)

Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2024			$	(10)	$	(11)	$	(21)

Balance at December 31, 2022			$	(12)	$	(12)	$	(24)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

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


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI components	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2024		2023
Sempra:
Financial instruments:
Interest rate instruments	$	(3)	$	—	Interest Expense
Interest rate instruments	(10)		(14)		Equity Earnings(1)
Foreign exchange instruments	(2)		—		Revenues: Energy-Related Businesses
	(1)		1		Other Income, Net
Foreign exchange instruments	(2)		1		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		(1)		Interest Expense
Total, before income tax	(18)		(13)
	3		—		Income Tax Benefit (Expense)
Total, net of income tax	(15)		(13)
	5		9		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(10)	$	(4)

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	1	Other Income, Net

Settlement charges	9		—		Other Income, Net
Total, before income tax	10		1
	(3)		—		Income Tax Benefit (Expense)
Total, net of income tax	$	7	$	1

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





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






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

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

(2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below).


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about AOCI components	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2024		2023
Sempra:
Financial instruments:
Interest rate instruments	$	(6)	$	—	Interest Expense
Interest rate instruments	(15)		(21)		Equity Earnings(1)
Foreign exchange instruments	(5)		—		Revenues: Energy-Related Businesses
	(1)		2		Other Income, Net
Foreign exchange instruments	(4)		2		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		(1)		Interest Expense
	—		(6)		Other Income, Net
Total, before income tax	(31)		(24)
	6		3		Income Tax Benefit (Expense)
Total, net of income tax	(25)		(21)
	9		12		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(16)	$	(9)

Pension and PBOP(2):
Amortization of actuarial loss	$	3	$	1	Other Income, Net
Amortization of prior service cost	1		1		Other Income, Net
Settlement charges	9		—		Other Income, Net
Total, before income tax	13		2
	(4)		—		Income Tax Benefit (Expense)
Total, net of income tax	$	9	$	2

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





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

Pension and PBOP(2):

Amortization of prior service cost	$	1	$	1	Other Income (Expense), Net


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

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

(2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below).

For the three months and six months ended June 30, 2024 and 2023, reclassifications out of AOCI to net income were negligible for SDG&E.

PENSION AND PBOP

Net Periodic Benefit Cost

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


NET PERIODIC BENEFIT COST (CONTINUED)
(Dollars in millions)
	Pension				PBOP
	Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Service cost	$	65	$	57	$	7	$	7
Interest cost	83		79		18		19
Expected return on assets	(91)		(85)		(34)		(35)
Amortization of:
Prior service cost (credit)	3		2		(1)		(1)
Actuarial loss (gain)	6		4		(8)		(12)
Settlement charges	9		—		—		—
Net periodic benefit cost (credit)	75		57		(18)		(22)
Regulatory adjustments	1		58		18		22
Total expense recognized	$	76	$	115	$	—	$	—
SDG&E:
Service cost	$	19	$	16	$	2	$	1
Interest cost	22		20		3		4
Expected return on assets	(23)		(20)		(4)		(4)
Amortization of:
Actuarial loss (gain)	3		2		(1)		(1)
Net periodic benefit cost	21		18		—		—
Regulatory adjustments	(7)		8		—		—
Total expense recognized	$	14	$	26	$	—	$	—
SoCalGas:
Service cost	$	38	$	34	$	5	$	5
Interest cost	52		51		14		14
Expected return on assets	(61)		(60)		(30)		(30)
Amortization of:
Prior service cost (credit)	2		2		(1)		(1)
Actuarial gain	—		—		(6)		(10)
Net periodic benefit cost (credit)	31		27		(18)		(22)
Regulatory adjustments	8		50		18		22
Total expense recognized	$	39	$	77	$	—	$	—

OTHER INCOME, NET

Other Income, Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Allowance for equity funds used during construction	$	38	$	37	$	75	$	70
Investment gains, net(1)	3		5		19		17
Gains (losses) on interest rate and foreign exchange instruments, net	1		(1)		1		4
Foreign currency transaction (losses) gains, net	(2)		3		(1)		4
Non-service components of net periodic benefit cost	(32)		(26)		(4)		(51)
Interest on regulatory balancing accounts, net	24		19		42		37
Sundry, net	(2)		(6)		(3)		(9)
Total	$	30	$	31	$	129	$	72
SDG&E:
Allowance for equity funds used during construction	$	19	$	23	$	39	$	46
Non-service components of net periodic benefit cost	(3)		(5)		7		(9)
Interest on regulatory balancing accounts, net	11		11		18		21
Sundry, net	(4)		(7)		(8)		(8)
Total	$	23	$	22	$	56	$	50
SoCalGas:
Allowance for equity funds used during construction	$	19	$	14	$	36	$	24
Non-service components of net periodic benefit cost	(17)		(19)		4		(38)
Interest on regulatory balancing accounts, net	13		8		24		16
Sundry, net	(2)		(2)		(4)		(9)
Total	$	13	$	1	$	60	$	(7)

(1) Represents net investment gains 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.

INCOME TAXES

We provide our calculations of ETRs in the following table.


INCOME TAX (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2024			2023			2024			2023
Sempra:
Income tax (benefit) expense	$	(130)		$	175		$	42		$	551

Income before income taxes and equity earnings	$	308		$	523		$	1,013		$	1,852
Equity earnings, before income tax(1)	160			153			294			285
Pretax income	$	468		$	676		$	1,307		$	2,137

Effective income tax rate	(28)		%	26		%	3		%	26		%
SDG&E:
Income tax expense	$	34		$	4		$	74		$	11
Income before income taxes	$	220		$	188		$	483		$	453
Effective income tax rate	15		%	2		%	15		%	2		%
SoCalGas:
Income tax expense (benefit)	$	10		$	(21)		$	53		$	73
Income before income taxes	$	141		$	135		$	543		$	589
Effective income tax rate	7		%	(16)		%	10		%	12		%

(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, in 2023, the scope of projects eligible for ITCs was expanded to include standalone energy storage projects, which are transferable under the IRA. The IRA also provided an election through 2024 that permits ITCs related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset.

In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the three months and six months ended June 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. Sempra intends to elect this change in tax accounting method in its consolidated 2023 income tax return filing, and Sempra, SDG&E and SoCalGas have applied this methodology in the calculation of their 2024 forecasted ETRs.

Sempra, SDG&E, and SoCalGas record regulatory liabilities for benefits that will be flowed through to customers in the future.

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2024 USD ($) agreement
SDG&E \| Purchased-Power Contracts
Lessee, Lease, Description [Line Items]
Number of purchased-power contracts \| agreement	7
Number of purchase power contracts to be commenced the remainder of the year \| agreement	3
Number of purchase power contracts to be commenced in year one \| agreement	3
Number of purchase power contracts to be commenced in year two \| agreement	1
Future minimum lease payments due remainder of the year	$ 35
Future minimum lease payments due year one	69
Future minimum lease payments due year two	90
Future minimum lease payments due year three	92
Future minimum lease payments due year four	92
Future minimum lease payments due after year four	929
Sempra Infrastructure \| Tugboat Lease Agreement
Lessee, Lease, Description [Line Items]
Future minimum lease payments due year three	10
Future minimum lease payments due year four	12
Future minimum lease payments due after year four	210
Future minimum fixed payments	$ 184

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,484	$ 2,892	$ 6,181	$ 8,781
Utilities regulatory revenues	369	38	31	(121)
Other revenues	158	405	439	1,235
Total revenues	3,011	3,335	6,651	9,895
SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,047	1,400	2,509	3,165
Utilities regulatory revenues	308	(138)	225	(250)
Total revenues	1,355	1,262	2,734	2,915
SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,246	1,291	3,306	5,132
Utilities regulatory revenues	63	176	(192)	129
Total revenues	1,309	1,467	3,114	5,261
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,269	2,676	5,772	8,274
Utilities \| SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,047	1,400	2,509	3,165
Utilities \| SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,246	1,291	3,306	5,132
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	215	216	409	507
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,518	1,680	3,988	6,244
Gas \| SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	161	252	491	806
Gas \| SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,246	1,291	3,306	5,132
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	966	1,212	2,193	2,537
Electric \| SDG&E
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	886	1,148	2,018	2,359
Electric \| SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Sempra California
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,256	2,662	5,735	8,236
Utilities regulatory revenues	369	38	31	(121)
Other revenues	0	0	0	0
Total revenues	2,625	2,700	5,766	8,115
Operating Segments \| Sempra California \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,256	2,662	5,735	8,236
Operating Segments \| Sempra California \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Sempra California \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,374	1,518	3,724	5,883
Operating Segments \| Sempra California \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	882	1,144	2,011	2,353
Operating Segments \| Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	252	254	494	596
Utilities regulatory revenues	0	0	0	0
Other revenues	157	406	434	1,260
Total revenues	409	660	928	1,856
Operating Segments \| Sempra Infrastructure \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18	19	48	49
Operating Segments \| Sempra Infrastructure \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	234	235	446	547
Operating Segments \| Sempra Infrastructure \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	148	167	273	371
Operating Segments \| Sempra Infrastructure \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	104	87	221	225
Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(24)	(24)	(48)	(51)
Utilities regulatory revenues	0	0	0	0
Other revenues	1	(1)	5	(25)
Total revenues	(23)	(25)	(43)	(76)
Consolidating adjustments and Parent and other \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(5)	(5)	(11)	(11)
Consolidating adjustments and Parent and other \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(19)	(19)	(37)	(40)
Consolidating adjustments and Parent and other \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(4)	(5)	(9)	(10)
Consolidating adjustments and Parent and other \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (20)	$ (19)	$ (39)	$ (41)

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

Total

Series C Preferred Stock

Preferred stock

Common stock

Retained earnings

Series C Preferred Stock

Accumulated other comprehensive income (loss)

Sempra shareholders' equity

Series C Preferred Stock

Non- controlling interests

Beginning Balance at Dec. 31, 2022

$ 29,256

$ 889

$ 12,160

$ 14,201

$ (135)

$ 27,115

$ 2,141

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

1,908

1,595

313

$ (22)

(749)

Repurchases of common stock

(1)

(31)

595

(134)

729

(252)

Sale

255

237

Beginning Balance at Mar. 31, 2023

31,014

889

12,044

15,024

(121)

27,836

3,178

30,245

889

12,164

14,796

(182)

27,667

2,578

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

736

615

121

117

(11)

(375)

(1)

498

(134)

632

(209)

Beginning Balance at Dec. 31, 2023

31,014

889

12,044

15,024

(121)

27,836

3,178

33,654

^[1]

889

12,204

15,732

(150)

28,675

4,979

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

1,752

1,537

215

192

163

(22)

(785)

Issuances of common stock

(1)

Repurchases of common stock

(40)

786

(203)

Beginning Balance at Mar. 31, 2024

35,419

889

12,250

16,461

(121)

29,479

5,940

34,661

889

12,209

16,141

(104)

29,135

5,526

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

871

725

146

(17)

$ (11)

(393)

Issuances of common stock

(1)

312

(92)

$ 35,419

$ 889

$ 12,250

$ 16,461

$ (121)

$ 29,479

$ 5,940

[1]	Derived from audited financial statements.

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

Jun. 30, 2024

Dec. 31, 2023

Inventory [Line Items]

Natural gas

$ 147

$ 174

LNG

Materials and supplies

312

299

Total

467

482

^[1]

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

158

152

Total

159

153

^[1]

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

Inventory [Line Items]

Natural gas

132

155

LNG

Materials and supplies

128

122

Total

$ 260

$ 277

^[1]

[1]	Derived from audited financial statements.

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Jun. 30, 2024	Dec. 31, 2023
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	632,921,816	631,431,732
SDG&E
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	116,583,358	116,583,358

DEBT AND CREDIT FACILITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		3 Months Ended	6 Months Ended
	May 31, 2024 USD ($)	Mar. 31, 2024 USD ($)	May 30, 2024 USD ($)	Jun. 30, 2024 USD ($) bank lineOfCredit line_of_credit day	Dec. 31, 2023 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 9,900
Primary committed lines of credit \| lineOfCredit				7
Ratio of indebtedness to net capital (in percent)				0.65
Available unused credit				$ 7,958
6.875% Junior Subordinated Notes, Due October 1, 2054
Line of Credit Facility [Line Items]
Debt amount	$ 500	$ 600
Stated rate of debt (as a percent)				6.875%
Proceeds from debt issuance	489	593
Unamortized debt issuance costs and discounts	$ 11	7
Debt instrument, interest rate, period (in years)				5 years
Number of days before interest rate period \| day				2
Accrued interest			$ 7
6.875% Junior Subordinated Notes, Due October 1, 2054 \| Redemption period one
Line of Credit Facility [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)				100.00%
6.875% Junior Subordinated Notes, Due October 1, 2054 \| Redemption period two
Line of Credit Facility [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)				100.00%
6.875% Junior Subordinated Notes, Due October 1, 2054 \| Redemption period three
Line of Credit Facility [Line Items]
Debt instrument, redemption price, percentage of principal amount redeemed (in percent)				102.00%
6.875% Junior Subordinated Notes, Due October 1, 2054 \| Five-Year US Treasury Rate
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)				2.789%
Other Long-Term Debt, 4.125% Junior Subordinated Notes Due 2052
Line of Credit Facility [Line Items]
Stated rate of debt (as a percent)				4.125%
Other Long-Term Debt, 5.75% Junior Subordinated Notes Due 2079
Line of Credit Facility [Line Items]
Stated rate of debt (as a percent)				5.75%
ECA LNG Phase 1
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 200
Line of credit, amount outstanding				26
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 1,500
Ratio of indebtedness to net capital (in percent)				0.65
Available unused credit				$ 1,500
SDG&E \| Secured Debt \| Five Point Five Five Percent First Mortgage Bonds Due April 15, 2054
Line of Credit Facility [Line Items]
Debt amount		$ 600
Stated rate of debt (as a percent)		5.55%
Proceeds from debt issuance		$ 587
Unamortized debt issuance costs and discounts		13
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 1,200
Ratio of indebtedness to net capital (in percent)				0.65
Available unused credit				$ 1,094
SoCalGas \| 364-Day Term Loan, Due May 22,2025 \| Secured Overnight Financing Rate (SOFR) \| Variable Rate Component One
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)	0.80%
SoCalGas \| 364-Day Term Loan, Due May 22,2025 \| Secured Overnight Financing Rate (SOFR) \| Variable Rate Component Two
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)	0.10%
SoCalGas \| Secured Debt \| Five Point Six Percent First Mortgage Bonds, Due April 1, 2054
Line of Credit Facility [Line Items]
Debt amount		$ 500
Stated rate of debt (as a percent)		5.60%
Proceeds from debt issuance		$ 491
Unamortized debt issuance costs and discounts		$ 9
SoCalGas \| Line of Credit \| 364-Day Term Loan, Due May 22,2025 \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount	$ 500
Term of debt instrument (in years)	364 days
Proceeds from lines of credit	$ 300
Available unused credit	200
Line of credit facility, accordion feature, increase limit	$ 500
SI Partners
Line of Credit Facility [Line Items]
Maximum adjustment EBITDA allowed				5.25
SI Partners and IEnova
Line of Credit Facility [Line Items]
Number of lines of credit \| line_of_credit				3
IEnova \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)				83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)				16.60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Debt outstanding				$ 289	$ 258
Weighted average interest rate (as a percent)				5.33%	5.81%
Port Arthur LNG \| Domestic Line of Credit \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 6,800
Term of debt instrument (in years)				7 years
ECA LNG Phase 1 \| IEnova Committed Line Of Credit Due 2024 \| Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)				1.05%
ECA LNG Phase 1 \| IEnova Committed Line Of Credit Due 2024 \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)				1.15%
ECA LNG Phase 1 \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 1,300
Term of debt instrument (in years)				5 years
Number of banks in syndicate \| bank				7
Debt outstanding				$ 994	$ 832
Weighted average interest rate (as a percent)				8.29%	8.31%

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

3 Months Ended

6 Months Ended

Jun. 30, 2024

Jun. 30, 2023

Jun. 30, 2024

Jun. 30, 2023

Total other comprehensive income, net of tax amount, attributable to parent

^[1]

$ 28,675

$ (17)

$ 61

$ 14

Total accumulated other comprehensive income (loss)

29,479

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

(104)

(182)

(150)

(135)

(14)

Total other comprehensive income, net of tax amount, attributable to parent

(3)

(7)

(17)

Foreign currency translation adjustments

(121)

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

(33)

(49)

(36)

(59)

(16)

(13)

Total other comprehensive income, net of tax amount, attributable to parent

(16)

(13)

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

(49)

(38)

(49)

(38)

Financial instruments

(35)

Total other comprehensive income, net of tax amount, attributable to parent

(10)

(4)

(16)

(9)

(7)

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

Pension and PBOP

(113)

(98)

(117)

(86)

(1)

(13)

Total other comprehensive income, net of tax amount, attributable to parent

(11)

(107)

(97)

(107)

(97)

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

^[1]

9,902

SDG&E | Total accumulated other comprehensive income (loss)

10,311

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

(8)

(7)

(8)

(7)

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

(8)

(7)

(8)

(7)

SDG&E | Pension and PBOP

(8)

(7)

(8)

(7)

(8)

(7)

(8)

(7)

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

Total other comprehensive income, net of tax amount, attributable to parent

^[1]

7,410

SoCalGas | Total accumulated other comprehensive income (loss)

7,901

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

(22)

(23)

(24)

Total other comprehensive income, net of tax amount, attributable to parent

SoCalGas | Financial instruments

(21)

(22)

(21)

(22)

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

(11)

(12)

(11)

(12)

Total other comprehensive income, net of tax amount, attributable to parent

SoCalGas | Pension and PBOP

(10)

(11)

(10)

(11)

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

(11)

(12)

Total other comprehensive income, net of tax amount, attributable to parent

$ (11)

[1]	Derived from audited financial statements.

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

6 Months Ended

Jun. 30, 2024

USD ($)

Dec. 31, 2023

USD ($)

Jul. 01, 2020

project_owner

Property plant and equipment, net

$ 57,684

$ 54,960

^[1]

Finance lease obligations

1,319

1,340

Equity method investment

14,809

14,266

^[1]

Oncor Holdings | Sempra Texas Utilities

90,473

87,181

^[1]

Cameron LNG Holdings | Sempra Infrastructure

Equity method investment

14,809

14,266

Equity method investment

1,114

1,008

Property plant and equipment, net

24,250

23,549

^[1]

Finance lease obligations

1,213

1,233

$ 29,737

29,185

^[1]

IEnova | ECA LNG JV

Ownership percentage in consolidated entity (in percentage)

83.40%

Subsidiary of TOTAL SE | ECA LNG JV

Ownership percentage in consolidated entity (in percentage)

16.60%

Cameron LNG JV

Number of project owners | project_owner

Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure

Maximum exposure under guarantor obligations

$ 979

Variable Interest Entity, Not Primary Beneficiary | SDG&E

Property plant and equipment, net

1,151

1,166

Finance lease obligations

1,151

1,166

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

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

1,680

1,580

Liabilities

1,049

1,029

Beginning Balance at Dec. 31, 2022

5,019

3,927

Liabilities

$ 606

$ 600

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Pension
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 33	$ 29	$ 65	$ 57
Interest cost	41	39	83	79
Expected return on assets	(46)	(42)	(91)	(85)
Amortization of:
Prior service cost	2	1	3	2
Actuarial loss (gain)	3	2	6	4
Settlement charges	9	0	9	0
Net periodic benefit cost (credit)	42	29	75	57
Regulatory adjustments	26	29	1	58
Total expense recognized	68	58	76	115
Pension \| SDG&E
Defined Benefit Plan Disclosure [Line Items]
Service cost	9	8	19	16
Interest cost	11	10	22	20
Expected return on assets	(11)	(10)	(23)	(20)
Amortization of:
Actuarial loss (gain)	1	1	3	2
Net periodic benefit cost (credit)	10	9	21	18
Regulatory adjustments	3	4	(7)	8
Total expense recognized	13	13	14	26
Pension \| SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Service cost	19	17	38	34
Interest cost	26	26	52	51
Expected return on assets	(31)	(31)	(61)	(60)
Amortization of:
Prior service cost	1	1	2	2
Actuarial loss (gain)	0	0	0	0
Net periodic benefit cost (credit)	15	13	31	27
Regulatory adjustments	23	25	8	50
Total expense recognized	38	38	39	77
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	3	7	7
Interest cost	9	10	18	19
Expected return on assets	(17)	(18)	(34)	(35)
Amortization of:
Prior service cost	0	0	(1)	(1)
Actuarial loss (gain)	(4)	(6)	(8)	(12)
Settlement charges	0	0	0	0
Net periodic benefit cost (credit)	(9)	(11)	(18)	(22)
Regulatory adjustments	9	11	18	22
Total expense recognized	0	0	0	0
PBOP \| SDG&E
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	0	2	1
Interest cost	1	2	3	4
Expected return on assets	(1)	(2)	(4)	(4)
Amortization of:
Actuarial loss (gain)	(1)	0	(1)	(1)
Net periodic benefit cost (credit)	0	0	0	0
Regulatory adjustments	0	0	0	0
Total expense recognized	0	0	0	0
PBOP \| SoCalGas
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	2	5	5
Interest cost	7	7	14	14
Expected return on assets	(15)	(15)	(30)	(30)
Amortization of:
Prior service cost	0	0	(1)	(1)
Actuarial loss (gain)	(3)	(5)	(6)	(10)
Net periodic benefit cost (credit)	(9)	(11)	(18)	(22)
Regulatory adjustments	9	11	18	22
Total expense recognized	$ 0	$ 0	$ 0	$ 0

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

Total

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

SDG&E

Common stock

SDG&E

Retained earnings

SDG&E

Accumulated other comprehensive income (loss)

$ 29,256

$ 12,160

$ 14,201

$ (135)

$ 9,067

$ 1,660

$ 7,414

$ (7)

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

1,908

1,595

442

Beginning Balance at Mar. 31, 2023

31,014

12,044

15,024

(121)

9,509

1,660

7,856

(7)

30,245

12,164

14,796

(182)

9,325

1,660

7,672

(7)

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

736

615

184

Beginning Balance at Dec. 31, 2023

31,014

12,044

15,024

(121)

9,509

1,660

7,856

(7)

33,654

^[1]

12,204

15,732

(150)

9,902

1,660

8,250

(8)

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

1,752

1,537

409

Beginning Balance at Mar. 31, 2024

35,419

12,250

16,461

(121)

10,311

1,660

8,659

(8)

34,661

12,209

16,141

(104)

10,125

1,660

8,473

(8)

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

871

725

186

$ 35,419

$ 12,250

$ 16,461

$ (121)

$ 10,311

$ 1,660

$ 8,659

$ (8)

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

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 6
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483443/250-10-50-6

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 805
-SubTopic 60
-Name Accounting Standards Codification
-Section 65
-Paragraph 1
-Subparagraph (g)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147476176/805-60-65-1

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 805
-SubTopic 60
-Name Accounting Standards Codification
-Section 65
-Paragraph 1
-Subparagraph (d)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147476176/805-60-65-1

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 323
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478666/740-323-65-2

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 323
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (g)(4)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478666/740-323-65-2

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 323
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (d)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478666/740-323-65-2

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 740
-SubTopic 323
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (d)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478666/740-323-65-2

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (a)(3)(iii)(03)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483550/848-10-65-2

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 842
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 8
-Subparagraph (c)(3)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479832/842-10-65-8

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 24
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483421/250-10-45-24

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 23
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483421/250-10-45-23

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 5
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483421/250-10-45-5

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 326
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 5
-Subparagraph (c)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479654/326-10-65-5

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 6
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480528/815-20-65-6

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 6
-Subparagraph (h)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480528/815-20-65-6

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 6
-Subparagraph (h)(1)(i)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480528/815-20-65-6

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 6
-Subparagraph (h)(1)(iii)
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-URI https://asc.fasb.org/1943274/2147480528/815-20-65-6

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Commitments and Contingencies Disclosure [Abstract]

COVER - shares	6 Months Ended
COVER - shares	Jun. 30, 2024	Aug. 01, 2024
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2024
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		633,145,875
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
SDG&E
Document Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8330 Century Park Court
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92123
City Area Code	(619)
Local Phone Number	696-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0000086521
SoCalGas
Document Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West 5th Street
Entity Address, City or Town	Los Angeles
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90013
City Area Code	(213)
Local Phone Number	244-1200
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0000092108
Common stock
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
5.75% Junior Subordinated Notes Due 2079
Document Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE

COMMITMENTS AND CONTINGENCIES (Tables)

6 Months Ended

Jun. 30, 2024

Lessor Information on the Condensed Consolidated Statements of Operations

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


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra – Sales-type leases:
Interest income	$	2	$	1	$	3	$	3
Total revenues from sales-type leases(1)	$	2	$	1	$	3	$	3

Sempra – Operating leases:
Fixed lease payments	$	87	$	76	$	176	$	156
Variable lease payments	10		14		20		16
Total revenues from operating leases(1)	$	97	$	90	$	196	$	172

Depreciation expense	$	18	$	15	$	36	$	30

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

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

Jun. 30, 2024

Dec. 31, 2023

Total due to unconsolidated affiliates – noncurrent

$ 7

$ 31

^[1]

(302)

(307)

^[1]

Total due to unconsolidated affiliates – noncurrent

(3)

(5)

^[1]

(302)

(307)

Various affiliates

Tax Sharing Arrangement | Related Party

(3)

^[1]

SDG&E | Related Party

SDG&E | Various affiliates

(40)

(73)

^[1]

SDG&E | Due to/from Sempra Energy

(13)

(8)

Income taxes due from Sempra

(27)

(44)

223

246

SDG&E | Due to/from SoCalGas

(21)

^[1]

SoCalGas | Related Party

SoCalGas | Various affiliates

(42)

(38)

^[1]

SoCalGas | Due to/from Sempra Energy

Income taxes due from Sempra

(34)

(38)

SoCalGas | Due to/from SDG&E

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

(8)

$ 0

(5)

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

5.50%

Total due to unconsolidated affiliates – noncurrent

5.50%

$ 0

(24)

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

Total due to unconsolidated affiliates – noncurrent

5.50%

$ 0

(23)

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

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (8)

(20)

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

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (12)

(11)

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

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (15)

(14)

Five Point Five Percent Note due July 2027 | TAG Pipeline | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (18)

(17)

Five Point Five Percent Note due January 2028 | TAG Pipeline | Related Party

Total due to unconsolidated affiliates – noncurrent

5.50%

$ (46)

Five Point Seven Four Percent Note December 2029 | TAG JV Norte | Related Party

Total due to unconsolidated affiliates – noncurrent

5.74%

$ (203)

$ (198)

[1]	Derived from audited financial statements.

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,420	$ 1,970
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,371	1,951
Accounts receivable – trade, net \| Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	135	148
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	23	15
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	4
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	20	0
SDG&E
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	718	889
SDG&E \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	684	870
SDG&E \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	19	13
SDG&E \| Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	8	6
SDG&E \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	7	0
SoCalGas
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	600	987
SoCalGas \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	583	985
SoCalGas \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	4	2
SoCalGas \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 13	$ 0

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS & ENVIRONMENTAL ISSUES (Details) $ in Millions	6 Months Ended
	Jun. 30, 2024 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	$ 44
Sempra Infrastructure \| Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Increase (decrease) in unrecorded unconditional purchase obligation, remainder of fiscal year	(241)
Increase (decrease) in unrecorded unconditional purchase obligation, year one	22
Increase (decrease) in unrecorded unconditional purchase obligation, year two	47
Increase (decrease) in unrecorded unconditional purchase obligation, year three	37
Increase (decrease) in unrecorded unconditional purchase obligation, year four	14
Increase (decrease) in unrecorded unconditional purchase obligation, after four years	7
SDG&E
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	15
SoCalGas
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	20
SoCalGas \| Natural Gas Contracts And Transportation Commitments
Loss Contingencies [Line Items]
Increase (decrease) in unrecorded unconditional purchase obligation	379
Increase (decrease) in unrecorded unconditional purchase obligation, remainder of fiscal year	(1)
Increase (decrease) in unrecorded unconditional purchase obligation, year one	43
Increase (decrease) in unrecorded unconditional purchase obligation, year two	123
Increase (decrease) in unrecorded unconditional purchase obligation, year three	128
Increase (decrease) in unrecorded unconditional purchase obligation, year four	$ 86

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Jun. 30, 2024	Dec. 31, 2023
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	632,921,816	631,431,732
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES NARRATIVE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (130)	$ 175	$ 42	$ 551
SoCalGas
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ 10	(21)	$ 53	73
SoCalGas \| Cumulative Effect, Period of Adoption, Adjustment [Member]
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)		$ 43		$ 43

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

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Debt Securities, Available-for-sale [Line Items]
Cost	$ 667		$ 667		$ 661
Gross unrealized gains	239		239		233
Gross unrealized losses	(24)		(24)		(22)
Estimated fair value	882		882		872
Proceeds from sales	199	$ 138	380	$ 294
Gross realized gains	10	6	24	8
Gross realized losses	3	$ 3	5	$ 6
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	23		23		21
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	23		23		21
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	90		90		89
Gross unrealized gains	235		235		225
Gross unrealized losses	(4)		(4)		(2)
Estimated fair value	321		321		312
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	577		577		558
Gross unrealized gains	4		4		8
Gross unrealized losses	(20)		(20)		(20)
Estimated fair value	561		561		546
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	61		61		50
Gross unrealized gains	1		1		2
Gross unrealized losses	(1)		(1)		(1)
Estimated fair value	61		61		51
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	281		281		280
Gross unrealized gains	1		1		3
Gross unrealized losses	(9)		(9)		(8)
Estimated fair value	273		273		275
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	235		235		228
Gross unrealized gains	2		2		3
Gross unrealized losses	(10)		(10)		(11)
Estimated fair value	227		227		220
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(23)		(23)		(7)
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (23)		$ (23)		$ (7)

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES

6 Months Ended

Jun. 30, 2024

Investments [Abstract]

SEMPRA – INVESTMENTS IN UNCONSOLIDATED ENTITIES

We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Condensed Consolidated Statements of Operations. Distributions received from equity method investees are classified in the Condensed Consolidated Statements of Cash Flows as either a return on investment in operating activities or a return of investment in investing activities based on the “nature of the distribution” approach. See Note 12 for information on equity earnings and losses, both before and net of income tax, by segment. See Note 1 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.

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

ONCOR HOLDINGS

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

In the six months ended June 30, 2024 and 2023, Sempra contributed $385 million and $178 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $214 million and $204 million, respectively, to Sempra.

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


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Operating revenues	$	1,492	$	1,343	$	2,950	$	2,635
Operating expenses	(1,043)		(976)		(2,094)		(2,000)
Income from operations	449		367		856		635
Interest expense	(161)		(133)		(311)		(256)
Income tax expense	(55)		(43)		(104)		(67)
Net income	248		197		471		296
NCI held by Texas Transmission Investment LLC	(50)		(40)		(94)		(60)
Earnings attributable to Sempra(1)	198		157		377		236

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

CAMERON LNG JV

In the six months ended June 30, 2024 and 2023, Sempra Infrastructure contributed $2 million and $6 million, respectively, to Cameron LNG JV, and Cameron LNG JV distributed $204 million and $198 million, respectively, to Sempra Infrastructure.

Sempra Promissory Note for SDSRA Distribution

Cameron LNG JV’s debt agreements require Cameron LNG JV to maintain the SDSRA, which is an additional reserve account beyond the Senior Debt Service Accrual Account, where funds accumulate from operations to satisfy senior debt obligations due and payable on the next payment date. Both accounts can be funded with cash or authorized investments. In June 2021, Sempra Infrastructure received a distribution of $165 million based on its proportionate share of the SDSRA, for which Sempra provided a promissory note and letters of credit to secure a proportionate share of Cameron LNG JV’s obligation to fund the SDSRA. Sempra’s maximum exposure to loss is replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $19 million at June 30, 2024, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra Infrastructure’s investment in Cameron LNG JV. The guarantee will terminate upon full repayment of Cameron LNG JV’s debt, scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA.

Sempra Support Agreement for CFIN

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

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

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

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

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

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

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

In exchange for this guarantee, the external lenders pay a guarantee fee that is based on the credit rating of Sempra’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra Infrastructure recognizes as interest income as earned. Sempra’s maximum exposure to loss is the bank debt plus any accrued and unpaid interest and related fees, subject to a liability cap of 130% of the bank debt, or $979 million. We measure the Support Agreement at fair value, net of related guarantee fees, on a recurring basis (see Note 8). At June 30, 2024, the fair value of the Support Agreement was $23 million, of which $7 million is included in Other Current Assets and $16 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

TAG NORTE

In the six months ended June 30, 2024 and 2023, TAG Norte distributed $62 million and $36 million, respectively, to Sempra Infrastructure.

CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,752	$ 1,908
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,197	1,088
Deferred income taxes and investment tax credits	(34)	323
Bad debt expense	94	220
Other	(5)	(19)
Net change in working capital components	(99)	1,474
Changes in other noncurrent assets and liabilities, net	(78)	(514)
Net cash provided by operating activities	2,520	3,737
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,830)	(4,282)
Net cash used in investing activities	(4,168)	(4,421)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(22)	(22)
Issuances of debt (maturities greater than 90 days)	3,812	5,614
Payments on debt (maturities greater than 90 days) and finance leases	(1,197)	(3,392)
(Decrease) increase in short-term debt, net	(817)	(388)
Net cash provided by financing activities	1,618	1,457
(Decrease) increase in cash, cash equivalents and restricted cash	(38)	780
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, June 30	351	1,242
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	574	612
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	885	863
Increase in finance lease obligations for investment in PP&E	12	36
Decrease in ARO for investment in PP&E	(2)	(46)
SoCalGas
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	490	516
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	447	414
Deferred income taxes and investment tax credits	56	79
Bad debt expense	45	160
Other	(13)	(4)
Net change in working capital components	73	40
Changes in other noncurrent assets and liabilities, net	(52)	(280)
Net cash provided by operating activities	1,046	925
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(978)	(961)
Net cash used in investing activities	(978)	(961)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)	(1)
Issuances of debt (maturities greater than 90 days)	797	997
Payments on debt (maturities greater than 90 days) and finance leases	(11)	(1,109)
(Decrease) increase in short-term debt, net	(840)	138
Debt issuance costs	(5)	(9)
Net cash provided by financing activities	(60)	16
(Decrease) increase in cash, cash equivalents and restricted cash	8	(20)
Cash, cash equivalents and restricted cash, January 1	2	21
Cash, cash equivalents and restricted cash, June 30	10	1
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	142	138
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	222	222
Increase in finance lease obligations for investment in PP&E	10	32
Decrease in ARO for investment in PP&E	$ (2)	$ (56)

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE

6 Months Ended

Jun. 30, 2024

Earnings Per Share [Abstract]

SEMPRA – EQUITY AND EARNINGS PER COMMON SHARE

PREFERRED STOCK

On May 2, 2024, Sempra filed an amendment to its amended and restated articles of incorporation to implement the revocation of the series A preferred stock and series B preferred stock, all of which had previously been converted to Sempra common stock, thereby decreasing the number of authorized shares of series A preferred stock from 17,250,000 to zero and series B preferred stock from 5,750,000 to zero. Effective as of May 2, 2024, each such series of stock is no longer an authorized series of Sempra’s capital stock.

COMMON STOCK SPLIT IN THE FORM OF A STOCK DIVIDEND

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

Except as expressly noted, all share and per share information related to issued and outstanding common stock and outstanding equity awards with respect to common stock has been retroactively adjusted to reflect the stock split and is presented on a post-split basis herein.

COMMON STOCK OFFERING

In November 2023, we completed the offering of 19,242,010 shares of our common stock, no par value, in a registered public offering at $70.00 per share ($68.845 per share after deducting underwriting discounts), 17,142,858 shares of which were pursuant to forward sale agreements. We discuss the common stock offering in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.

As of August 6, 2024, a total of 17,142,858 shares of Sempra common stock from our November 2023 offering remain subject to future settlement under these forward sale agreements, which may be settled on one or more dates specified by us occurring no later than December 31, 2024, which is the final settlement date under the agreements. Although we expect to settle the forward sale agreements entirely by the physical delivery of shares of our common stock in exchange for cash proceeds, we may, subject to certain conditions, elect cash settlement or net share settlement for all or a portion of our obligations under the forward sale agreements. The forward sale agreements are also subject to acceleration by the counterparties to the agreements upon the occurrence of certain events.

COMMON STOCK REPURCHASES

In the six months ended June 30, 2024 and 2023, we withheld 555,888 shares for $40 million and 395,540 shares for $31 million, respectively, of our common stock that would otherwise be issued to long-term incentive plan participants who do not elect otherwise upon the vesting of RSUs and exercise of stock options in an amount sufficient to satisfy minimum statutory tax withholding requirements. Such share withholding is considered a share repurchase for accounting purposes.

NONCONTROLLING INTERESTS

Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI.

The following table summarizes net income attributable to Sempra and transfers (to) from NCI, which shows the effects of changes in Sempra’s ownership interest in its subsidiaries on Sempra’s shareholders’ equity.


NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI
(Dollars in millions)
	Three months ended June 30, 2023		Six months ended June 30, 2023
Sempra:
Net income attributable to Sempra	$	615	$	1,595
Transfers (to) from NCI:
Increase in shareholders’ equity for sale of NCI	—		18
Net transfers (to) from NCI	—		18
Change from net income attributable to Sempra and transfers (to) from NCI	$	615	$	1,613

SI Partners Subsidiaries

Sale of NCI to ConocoPhillips Affiliate. In March 2023, an indirect subsidiary of SI Partners completed the sale of an indirect 30% interest in an SI Partners subsidiary (resulting in an indirect 30% NCI in the PA LNG Phase 1 project) to an affiliate of ConocoPhillips for aggregate cash consideration of $265 million, before post-closing adjustments recorded subsequently. 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 expense.

The indirect subsidiary of SI Partners and the ConocoPhillips affiliate have made certain customary capital contribution commitments to fund their respective pro rata equity share of the total anticipated capital calls for the equity portion of the anticipated development costs of the PA LNG Phase 1 project. In addition, both SI Partners and ConocoPhillips have provided guarantees relating to their respective affiliate’s commitment to make its pro rata equity share of capital contributions to fund 110% of the development budget of the PA LNG Phase 1 project, in an aggregate amount of up to $9.0 billion. SI Partners’ guarantee covers 70% of this amount plus enforcement costs of its guarantee. As of June 30, 2024, an aggregate amount of $2.4 billion has been paid by SI Partners’ indirect subsidiary in satisfaction of its commitment to fund its portion of the development budget of the PA LNG Phase 1 project.

EARNINGS PER COMMON SHARE

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


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Numerator:
Earnings attributable to common shares	$	713	$	603	$	1,514	$	1,572

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	633,450		630,014		633,135		629,926
Dilutive effect of common shares sold forward	1,139		—		906		—
Dilutive effect of stock options and RSUs(2)	1,690		2,107		1,776		2,259
Weighted-average common shares outstanding for diluted EPS	636,279		632,121		635,817		632,185

EPS:
Basic	$	1.13	$	0.96	$	2.39	$	2.50
Diluted	$	1.12	$	0.95	$	2.38	$	2.49

(1) Includes 610 and 710 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2024 and 2023, respectively, and 617 and 715 of such RSUs for the six months ended June 30, 2024 and 2023, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and six months ended June 30, 2024 excludes 1,184,115 and 1,270,327 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and six months ended June 30, 2023 excludes 428,138 and 394,084 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we discuss above is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of our common stock shares is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS.

Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Development Committee of Sempra’s board of directors granted 414,812 nonqualified stock options, 721,049 performance-based RSUs and 312,043 service-based RSUs in the six months ended June 30, 2024, primarily in January.

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

The entire disclosure for equity.

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DEBT AND CREDIT FACILITIES

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Allowance for credit losses	$ 6	$ 6
Unamortized transaction costs	4	4
Unamortized discount and debt issuance costs	346	322
Finance lease obligations	1,319	1,340
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	342	334
Long-term amounts due to unconsolidated affiliates	302	312
Total long-term debt	29,704	27,716
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	326	318
Long-term amounts due to unconsolidated affiliates	271	283
Total long-term debt	26,850	25,617
Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0	0
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0	0
Long-term amounts due to unconsolidated affiliates	271	283
Total long-term debt	26,850	25,617
Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	326	318
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
SDG&E
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	98	89
Finance lease obligations	1,213	1,233
SDG&E \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,950	8,750
SDG&E \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,747	7,856
SDG&E \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SDG&E \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,747	7,856
SDG&E \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SoCalGas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	61	55
Finance lease obligations	106	107
SoCalGas \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,259	6,759
SoCalGas \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,715	6,442
SoCalGas \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
SoCalGas \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,715	6,442
SoCalGas \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

COMMITMENTS AND CONTINGENCIES - NARRATIVE (Details) £ in Millions, $ in Millions		1 Months Ended	3 Months Ended		4 Months Ended	6 Months Ended		12 Months Ended			48 Months Ended
	Aug. 01, 2024 lawsuit plaintiff claim	Sep. 30, 2021 USD ($) lawsuit plaintiff	Jun. 30, 2024 USD ($)	Jun. 30, 2023 USD ($)	Feb. 11, 2016 well	Jun. 30, 2024 USD ($)	Jun. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2023 GBP (£)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 lawsuit claimant	Jul. 31, 2024 lawsuit	Aug. 31, 2023 Bcf	Mar. 31, 2021 lawsuit	Dec. 31, 2015 company
Loss Contingencies [Line Items]
Liability for legal proceedings			$ 52			$ 52
Number of liquidating companies \| company															10
Equity earnings			433	$ 388		781	$ 607
Sempra Infrastructure
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit														3
Number of claimants \| claimant											3
Subsequent Event \| Sempra Infrastructure
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit												2
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit		390
Number of lawsuits \| plaintiff		36,000
HMRC VAT Claim
Loss Contingencies [Line Items]
Damages awarded								$ 10	£ 7.9
Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs		$ 1,800
Percentage of plaintiffs agreeing to participate and submit releases (in percent)										99.00%
Non-Settling Individual Plaintiffs \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of lawsuits \| plaintiff	550
RBS Sempra Commodities
Loss Contingencies [Line Items]
Equity earnings								$ 40
SoCalGas
Loss Contingencies [Line Items]
Liability for legal proceedings			27			27
Wells with gas leak \| well					1
Natural gas inventory level (in bcf) \| Bcf													68.6
SoCalGas \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit		390
Number of lawsuits \| plaintiff		36,000
Net book value of Aliso Canyon facility			1,000			1,000
SoCalGas \| Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs		$ 1,800
Percentage of plaintiffs agreeing to participate and submit releases (in percent)										99.00%
Payment of liquidating companies' costs										$ 1,790
SoCalGas \| Non-Settling Individual Plaintiffs \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of lawsuits \| plaintiff	550
SDG&E
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit											2
Energy Future Holdings Corp. \| Subsequent Event
Loss Contingencies [Line Items]
Lawsuits pending \| lawsuit	0
Number of proof of claims \| claim	28,000
Deferred Credits and Other \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Payable related to natural gas leak			1			1
Deferred Credits and Other \| SoCalGas \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Payable related to natural gas leak			1			1
Other Current Liabilities [Member] \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Payable related to natural gas leak			26			26
Other Current Liabilities [Member] \| SoCalGas \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Payable related to natural gas leak			$ 26			$ 26

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares, basic	$ 713	$ 603	$ 1,514	$ 1,572
Earnings attributable to common shares, diluted	$ 713	$ 603	$ 1,514	$ 1,572
Weighted-average common shares outstanding for basic EPS (in shares)	633,450,000	630,014,000	633,135,000	629,926,000
Dilutive effect of common shares sold forward (in shares)	1,139,000	0	906,000	0
Dilutive effect of stock options and RSUs (in shares)	1,690,000	2,107,000	1,776,000	2,259,000
Weighted-average common shares outstanding for diluted EPS (in shares)	636,279,000	632,121,000	635,817,000	632,185,000
Earnings per share, basic (dollars per share)	$ 1.13	$ 0.96	$ 2.39	$ 2.50
Earnings per share, diluted (in dollars per share)	$ 1.12	$ 0.95	$ 2.38	$ 2.49
Vested RSUs included in basic WASO (in shares)	610,000	710,000	617,000	715,000
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)			414,812
Performance-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			721,049
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			312,043
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	1,184,115	428,138	1,270,327	394,084

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (198)	$ (252)
Revenue from performance obligations satisfied during reporting period	3	5
Payments received in advance	(3)	(2)
Contract liabilities, closing balance	(198)	(249)
Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(5)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(193)
SDG&E
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(75)	(79)
Revenue from performance obligations satisfied during reporting period	2	2
Contract liabilities, closing balance	(73)	$ (77)
SDG&E \| Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(3)
SDG&E \| Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ (70)

DEBT AND CREDIT FACILITIES

6 Months Ended

Jun. 30, 2024

Debt Disclosure [Abstract]

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

SHORT-TERM DEBT

Committed Lines of Credit

At June 30, 2024, Sempra had an aggregate capacity of $9.9 billion under seven primary committed lines of credit, which provide liquidity and support our commercial paper programs. Because our commercial paper programs are supported by some of these lines of credit, we reflect the amount of commercial paper outstanding, before reductions of any unamortized discounts, and any letters of credit outstanding as a reduction to the available unused credit capacity in the following table.


COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2024
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Letters of credit outstanding		Available unused credit
Sempra	October 2028	$	4,000	$	(746)	$	—	$	—	$	3,254
SDG&E	October 2028	1,500		—		—		—		1,500
SoCalGas	October 2028	1,200		(106)		—		—		1,094
SI Partners and IEnova	September 2025	500		—		(350)		—		150
SI Partners and IEnova	August 2026	1,000		—		(25)		—		975
SI Partners and IEnova	August 2028	1,500		—		(651)		—		849
Port Arthur LNG	March 2030	200		—		—		(64)		136
Total		$	9,900	$	(852)	$	(1,026)	$	(64)	$	7,958

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At June 30, 2024, each Registrant was in compliance with this ratio under its respective credit facility.

The three lines of credit that are shared by SI Partners and IEnova require that SI Partners maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in each credit facility) of no more than 5.25 to 1.00 at the end of each quarter. At June 30, 2024, SI Partners was in compliance with this ratio.

Uncommitted Line of Credit

ECA LNG Phase 1 has an uncommitted line of credit, which is generally used for working capital requirements, with an aggregate capacity of $200 million of which $26 million was outstanding at June 30, 2024. The amounts outstanding are before reductions of any unamortized discounts. Borrowings can be in U.S. dollars or Mexican pesos. At June 30, 2024, 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 one-month or three-month SOFR plus 115 bps. The uncommitted line of credit expires on August 12, 2024.

Uncommitted Letters of Credit

Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At June 30, 2024, we had $499 million in standby letters of credit outstanding under these agreements.


UNCOMMITTED LETTERS OF CREDIT OUTSTANDING
(Dollars in millions)
	Expiration date range	June 30, 2024
SDG&E	November 2024 - June 2025	$	26
SoCalGas	October 2024 - June 2025	20
Other Sempra	July 2024 - November 2054	453
Total Sempra		$	499

Term Loan

In May 2024, SoCalGas entered into a $500 million, 364-day term loan facility with a maturity date of May 22, 2025. Upon execution, SoCalGas borrowed $300 million, net of negligible debt issuance costs, under the term loan facility and is able to borrow up to an additional $200 million by August 23, 2024. SoCalGas may request an increase in the term loan facility of up to $500 million prior to the maturity date, subject to lender approval. The outstanding borrowings bear interest at a per annum rate equal to term SOFR, plus 80 bps and a credit adjustment spread of 10 bps. SoCalGas used the proceeds to repay commercial paper and for other general corporate purposes. At June 30, 2024, the term loan is included in Short-Term Debt on SoCalGas’ Condensed Consolidated Balance Sheet.

Weighted-Average Interest Rates

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


WEIGHTED-AVERAGE INTEREST RATES

	June 30, 2024		December 31, 2023
Sempra	6.07	%	5.96	%

SoCalGas	6.02		5.44

LONG-TERM DEBT

SDG&E

In March 2024, SDG&E issued $600 million aggregate principal amount of 5.55% first mortgage bonds due in full upon maturity on April 15, 2054 and received proceeds of $587 million (net of debt discount, underwriting discounts and debt issuance costs of $13 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SDG&E used the net proceeds to repay commercial paper and for other general corporate purposes.

SoCalGas

In March 2024, SoCalGas issued $500 million aggregate principal amount of 5.6% first mortgage bonds due in full upon maturity on April 1, 2054 and received proceeds of $491 million (net of debt discount, underwriting discounts and debt issuance costs of $9 million). The first mortgage bonds are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SoCalGas used the net proceeds to repay outstanding indebtedness and for other general corporate purposes.

Sempra

In March 2024 and May 2024, Sempra issued $600 million and $500 million, respectively, of 6.875% fixed-to-fixed reset rate junior subordinated notes maturing on October 1, 2054. Interest on the notes accrues from and including March 14, 2024 and is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on October 1, 2024. The notes bear interest (i) from and including March 14, 2024 to, but excluding, October 1, 2029 at the rate of 6.875% per annum and (ii) from and including October 1, 2029, during each subsequent five-year period beginning on October 1 of every fifth year, at a rate per annum equal to the Five-year U.S. Treasury Rate (as defined in the notes) as of the day falling two business days before the first day of such five-year period plus a spread of 2.789%, to be reset on October 1 of every fifth year beginning in 2029. In March 2024, we received proceeds of $593 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million). In May 2024, we received proceeds of $489 million (net of debt discount, underwriting discounts and debt issuance costs of $11 million, but excluding $7 million paid to us in respect of accrued interest from and including March 14, 2024 to, but excluding, May 31, 2024). We used the proceeds from the offerings for general corporate purposes, including repayment of commercial paper and other indebtedness. We may redeem some or all of the notes before their maturity, as follows:

▪in whole or in part, (i) on any day in the period commencing on the date falling 90 days prior to October 1, 2029 and ending on and including October 1, 2029 and (ii) after October 1, 2029, on any interest payment date, at a redemption price in cash equal to 100% of the principal amount of the notes being redeemed, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to be redeemed to, but excluding, the redemption date;

▪in whole but not in part, at any time following the occurrence and during the continuance of a tax event (as defined in the notes) at a redemption price in cash equal to 100% of the principal amount of the notes, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to, but excluding, the redemption date; and

▪in whole but not in part, at any time following the occurrence and during the continuance of a rating agency event (as defined in the notes) at a redemption price in cash equal to 102% of the principal amount of the notes, plus, subject to the terms of the notes, accrued and unpaid interest on the notes to, but excluding, the redemption date.

The notes are unsecured obligations and rank junior and subordinate in right of payment to our existing and future senior indebtedness. The notes rank equally in right of payment with our existing 4.125% fixed-to-fixed reset rate junior subordinated notes due 2052 and 5.75% junior subordinated notes due 2079 and with any future unsecured indebtedness that we may incur if the terms of such indebtedness provide that it ranks equally with the notes in right of payment. The notes are effectively subordinated in right of payment to any secured indebtedness we have incurred or may incur (to the extent of the value of the collateral securing such secured indebtedness) and to all existing and future indebtedness and other liabilities and any preferred equity of our subsidiaries.

Other Sempra

ECA LNG Phase 1

ECA LNG Phase 1 has a five-year loan agreement with a syndicate of seven external lenders that matures on December 9, 2025 for an aggregate principal amount of up to $1.3 billion. IEnova and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest of 83.4% and 16.6%, respectively. At June 30, 2024 and December 31, 2023, $994 million and $832 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 8.29% and 8.31%, respectively.

Port Arthur LNG

Port Arthur LNG has a seven-year term loan facility agreement with a syndicate of lenders that matures on March 20, 2030 for an aggregate principal amount of approximately $6.8 billion. At June 30, 2024 and December 31, 2023, $289 million and $258 million, respectively, of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.33% and 5.81%, respectively.

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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Organization, Consolidation and Presentation of Financial Statements [Abstract]

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)

6 Months Ended

Jun. 30, 2024

Schedule of Cash and Cash Equivalents


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Cash and cash equivalents	$	228	$	236
Restricted cash, current	16		49
Restricted cash, noncurrent	107		104
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	351	$	389

Accounts Receivable, Allowance for Credit Loss

Changes in allowances for credit losses for trade receivables and other receivables are as follows:


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2024		2023
Sempra:
Allowances for credit losses at January 1	$	533	$	181
Provisions for expected credit losses	94		228
Write-offs	(112)		(43)
Allowances for credit losses at June 30	$	515	$	366
SDG&E:
Allowances for credit losses at January 1	$	144	$	78
Provisions for expected credit losses	24		63
Write-offs	(42)		(23)
Allowances for credit losses at June 30	$	126	$	118
SoCalGas:
Allowances for credit losses at January 1	$	331	$	98
Provisions for expected credit losses	45		164
Write-offs	(70)		(20)
Allowances for credit losses at June 30	$	306	$	242

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


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2024		2023
Sempra:
Accounts receivable – trade, net	$	451	$	480
Accounts receivable – other, net	52		52
Other long-term assets	12		1
Total allowances for credit losses	$	515	$	533
SDG&E:
Accounts receivable – trade, net	$	96	$	116
Accounts receivable – other, net	26		27
Other long-term assets	4		1
Total allowances for credit losses	$	126	$	144
SoCalGas:
Accounts receivable – trade, net	$	272	$	306
Accounts receivable – other, net	26		25
Other long-term assets	8		—
Total allowances for credit losses	$	306	$	331

Schedule of Related Party Transactions

We summarize amounts due from and to unconsolidated affiliates at the Registrants in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Tax sharing arrangement with Oncor Holdings	$	—	$	25
Various affiliates	7		6
Total due from unconsolidated affiliates – current	$	7	$	31

Tax sharing arrangement with Oncor Holdings	$	(3)	$	—
TAG Pipelines – 5.5% Note due January 9, 2024(1)	—		(5)
Total due to unconsolidated affiliates – current	$	(3)	$	(5)

TAG Pipelines(1):
5.5% Note due January 14, 2025	$	—	$	(24)
5.5% Note due July 16, 2025	—		(23)
5.5% Note due January 14, 2026	(8)		(20)
5.5% Note due July 14, 2026	(12)		(11)
5.5% Note due January 19, 2027	(15)		(14)
5.5% Note due July 21, 2027	(18)		(17)
5.5% Note due January 19, 2028	(46)		—
TAG Norte – 5.74% Note due December 17, 2029(1)	(203)		(198)
Total due to unconsolidated affiliates – noncurrent	$	(302)	$	(307)
SDG&E:
SoCalGas	$	9	$	—
Total due from unconsolidated affiliates – current	$	9	$	—

Sempra	$	(27)	$	(44)
SoCalGas	—		(21)
Various affiliates	(13)		(8)
Total due to unconsolidated affiliates – current	$	(40)	$	(73)

Income taxes due from Sempra(2)	$	223	$	246
SoCalGas:
SDG&E	$	—	$	21
Various affiliates	1		1
Total due from unconsolidated affiliates – current	$	1	$	22

Sempra	$	(34)	$	(38)
SDG&E	(8)		—
Total due to unconsolidated affiliates – current	$	(42)	$	(38)

Income taxes due from Sempra(2)	$	10	$	6

(1) U.S. dollar-denominated loans at fixed interest rates. Amounts include principal balances plus accumulated interest outstanding and VAT payable to the Mexican government.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Revenues	$	10	$	11	$	20	$	24
Interest expense	3		4		7		8
SDG&E:
Revenues	$	5	$	6	$	11	$	10
Cost of sales	35		27		75		57
SoCalGas:
Revenues	$	37	$	28	$	81	$	62
Cost of sales(1)	—		4		(3)		35

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

Schedule of Inventory, Current

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023
Natural gas	$	147	$	174	$	1	$	1	$	132	$	155
LNG	8		9		—		—		—		—
Materials and supplies	312		299		158		152		128		122
Total	$	467	$	482	$	159	$	153	$	260	$	277

Schedule of Capitalization

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


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra	$	155	$	110	$	300	$	183
SDG&E	27		31		53		62
SoCalGas	26		20		50		35

Schedule of Accumulated Other Comprehensive Income (Loss)

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


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Three months ended June 30, 2024 and 2023
Sempra:
Balance at March 31, 2024	$	(33)	$	42	$	(113)	$	(104)
OCI before reclassifications	(16)		3		(1)		(14)
Amounts reclassified from AOCI	—		(10)		7		(3)
Net OCI	(16)		(7)		6		(17)
Balance at June 30, 2024	$	(49)	$	35	$	(107)	$	(121)

Balance at March 31, 2023	$	(49)	$	(35)	$	(98)	$	(182)
OCI before reclassifications	11		53		—		64
Amounts reclassified from AOCI	—		(4)		1		(3)
Net OCI	11		49		1		61
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
SDG&E:
Balance at March 31, 2024 and June 30, 2024					$	(8)	$	(8)





Balance at March 31, 2023 and June 30, 2023					$	(7)	$	(7)
SoCalGas:
Balance at March 31, 2024			$	(11)	$	(11)	$	(22)

Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2024			$	(10)	$	(11)	$	(21)

Balance at March 31, 2023			$	(12)	$	(11)	$	(23)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

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


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Six months ended June 30, 2024 and 2023
Sempra:
Balance at December 31, 2023	$	(36)	$	3	$	(117)	$	(150)
OCI before reclassifications	(13)		48		1		36
Amounts reclassified from AOCI	—		(16)		9		(7)
Net OCI	(13)		32		10		29
Balance at June 30, 2024	$	(49)	$	35	$	(107)	$	(121)

Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	21		13		(13)		21
Amounts reclassified from AOCI	—		(9)		2		(7)
Net OCI	21		4		(11)		14
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
SDG&E:
Balance at December 31, 2023 and June 30, 2024					$	(8)	$	(8)





Balance at December 31, 2022 and June 30, 2023					$	(7)	$	(7)
SoCalGas:
Balance at December 31, 2023			$	(11)	$	(12)	$	(23)

Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2024			$	(10)	$	(11)	$	(21)

Balance at December 31, 2022			$	(12)	$	(12)	$	(24)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at June 30, 2023			$	(11)	$	(11)	$	(22)

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

Reclassifications out of AOCI


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI components	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2024		2023
Sempra:
Financial instruments:
Interest rate instruments	$	(3)	$	—	Interest Expense
Interest rate instruments	(10)		(14)		Equity Earnings(1)
Foreign exchange instruments	(2)		—		Revenues: Energy-Related Businesses
	(1)		1		Other Income, Net
Foreign exchange instruments	(2)		1		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		(1)		Interest Expense
Total, before income tax	(18)		(13)
	3		—		Income Tax Benefit (Expense)
Total, net of income tax	(15)		(13)
	5		9		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(10)	$	(4)

Pension and PBOP(2):
Amortization of actuarial loss	$	1	$	1	Other Income, Net

Settlement charges	9		—		Other Income, Net
Total, before income tax	10		1
	(3)		—		Income Tax Benefit (Expense)
Total, net of income tax	$	7	$	1

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





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






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

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

(2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below).


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about AOCI components	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2024		2023
Sempra:
Financial instruments:
Interest rate instruments	$	(6)	$	—	Interest Expense
Interest rate instruments	(15)		(21)		Equity Earnings(1)
Foreign exchange instruments	(5)		—		Revenues: Energy-Related Businesses
	(1)		2		Other Income, Net
Foreign exchange instruments	(4)		2		Equity Earnings(1)
Interest rate and foreign exchange instruments	—		(1)		Interest Expense
	—		(6)		Other Income, Net
Total, before income tax	(31)		(24)
	6		3		Income Tax Benefit (Expense)
Total, net of income tax	(25)		(21)
	9		12		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(16)	$	(9)

Pension and PBOP(2):
Amortization of actuarial loss	$	3	$	1	Other Income, Net
Amortization of prior service cost	1		1		Other Income, Net
Settlement charges	9		—		Other Income, Net
Total, before income tax	13		2
	(4)		—		Income Tax Benefit (Expense)
Total, net of income tax	$	9	$	2

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





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

Pension and PBOP(2):

Amortization of prior service cost	$	1	$	1	Other Income (Expense), Net


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

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

(2) Amounts are included in the computation of net periodic benefit cost (see “Pension and PBOP” below).

Schedule of Net Benefit Costs


NET PERIODIC BENEFIT COST
(Dollars in millions)
	Pension				PBOP
	Three months ended June 30,
	2024		2023		2024		2023
Sempra:
Service cost	$	33	$	29	$	3	$	3
Interest cost	41		39		9		10
Expected return on assets	(46)		(42)		(17)		(18)
Amortization of:
Prior service cost	2		1		—		—
Actuarial loss (gain)	3		2		(4)		(6)
Settlement charges	9		—		—		—
Net periodic benefit cost (credit)	42		29		(9)		(11)
Regulatory adjustments	26		29		9		11
Total expense recognized	$	68	$	58	$	—	$	—
SDG&E:
Service cost	$	9	$	8	$	1	$	—
Interest cost	11		10		1		2
Expected return on assets	(11)		(10)		(1)		(2)
Amortization of:
Actuarial loss (gain)	1		1		(1)		—
Net periodic benefit cost	10		9		—		—
Regulatory adjustments	3		4		—		—
Total expense recognized	$	13	$	13	$	—	$	—
SoCalGas:
Service cost	$	19	$	17	$	2	$	2
Interest cost	26		26		7		7
Expected return on assets	(31)		(31)		(15)		(15)
Amortization of:
Prior service cost	1		1		—		—
Actuarial gain	—		—		(3)		(5)
Net periodic benefit cost (credit)	15		13		(9)		(11)
Regulatory adjustments	23		25		9		11
Total expense recognized	$	38	$	38	$	—	$	—


NET PERIODIC BENEFIT COST (CONTINUED)
(Dollars in millions)
	Pension				PBOP
	Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Service cost	$	65	$	57	$	7	$	7
Interest cost	83		79		18		19
Expected return on assets	(91)		(85)		(34)		(35)
Amortization of:
Prior service cost (credit)	3		2		(1)		(1)
Actuarial loss (gain)	6		4		(8)		(12)
Settlement charges	9		—		—		—
Net periodic benefit cost (credit)	75		57		(18)		(22)
Regulatory adjustments	1		58		18		22
Total expense recognized	$	76	$	115	$	—	$	—
SDG&E:
Service cost	$	19	$	16	$	2	$	1
Interest cost	22		20		3		4
Expected return on assets	(23)		(20)		(4)		(4)
Amortization of:
Actuarial loss (gain)	3		2		(1)		(1)
Net periodic benefit cost	21		18		—		—
Regulatory adjustments	(7)		8		—		—
Total expense recognized	$	14	$	26	$	—	$	—
SoCalGas:
Service cost	$	38	$	34	$	5	$	5
Interest cost	52		51		14		14
Expected return on assets	(61)		(60)		(30)		(30)
Amortization of:
Prior service cost (credit)	2		2		(1)		(1)
Actuarial gain	—		—		(6)		(10)
Net periodic benefit cost (credit)	31		27		(18)		(22)
Regulatory adjustments	8		50		18		22
Total expense recognized	$	39	$	77	$	—	$	—

Schedule of Other Nonoperating Income (Expense)

Other Income, Net, consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Allowance for equity funds used during construction	$	38	$	37	$	75	$	70
Investment gains, net(1)	3		5		19		17
Gains (losses) on interest rate and foreign exchange instruments, net	1		(1)		1		4
Foreign currency transaction (losses) gains, net	(2)		3		(1)		4
Non-service components of net periodic benefit cost	(32)		(26)		(4)		(51)
Interest on regulatory balancing accounts, net	24		19		42		37
Sundry, net	(2)		(6)		(3)		(9)
Total	$	30	$	31	$	129	$	72
SDG&E:
Allowance for equity funds used during construction	$	19	$	23	$	39	$	46
Non-service components of net periodic benefit cost	(3)		(5)		7		(9)
Interest on regulatory balancing accounts, net	11		11		18		21
Sundry, net	(4)		(7)		(8)		(8)
Total	$	23	$	22	$	56	$	50
SoCalGas:
Allowance for equity funds used during construction	$	19	$	14	$	36	$	24
Non-service components of net periodic benefit cost	(17)		(19)		4		(38)
Interest on regulatory balancing accounts, net	13		8		24		16
Sundry, net	(2)		(2)		(4)		(9)
Total	$	13	$	1	$	60	$	(7)

Schedule of Effective Income Tax Rate Reconciliation

We provide our calculations of ETRs in the following table.


INCOME TAX (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2024			2023			2024			2023
Sempra:
Income tax (benefit) expense	$	(130)		$	175		$	42		$	551

Income before income taxes and equity earnings	$	308		$	523		$	1,013		$	1,852
Equity earnings, before income tax(1)	160			153			294			285
Pretax income	$	468		$	676		$	1,307		$	2,137

Effective income tax rate	(28)		%	26		%	3		%	26		%
SDG&E:
Income tax expense	$	34		$	4		$	74		$	11
Income before income taxes	$	220		$	188		$	483		$	453
Effective income tax rate	15		%	2		%	15		%	2		%
SoCalGas:
Income tax expense (benefit)	$	10		$	(21)		$	53		$	73
Income before income taxes	$	141		$	135		$	543		$	589
Effective income tax rate	7		%	(16)		%	10		%	12		%

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

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - COMMON STOCK NARRATIVE (Details) $ / shares in Units, $ in Millions		1 Months Ended	6 Months Ended
	Aug. 02, 2023 shares	Nov. 30, 2023 $ / shares shares	Jun. 30, 2024 USD ($) shares	Jun. 30, 2023 USD ($) shares	Aug. 06, 2024 shares	Dec. 31, 2023 shares
Equity, Class of Treasury Stock [Line Items]
Stock split, conversion ratio	2
Stock dividend (in percent)	100.00%
Common stock, shares authorized (in shares)	1,125,000,000		1,125,000,000			1,125,000,000
Common stock
Equity, Class of Treasury Stock [Line Items]
Share repurchase program, number of shares repurchased (in shares)			555,888	395,540
Common stock repurchased \| $			$ 40	$ 31
Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Sale of stock, shares available for future settlement					17,142,858
Public Stock Offering
Equity, Class of Treasury Stock [Line Items]
Sale of stock, number of shares issued in transaction		19,242,010
Common stock, par or stated value per share (usd per share) \| $ / shares		$ 0
Sale of stock, price per share (usd per share) \| $ / shares		70.00
Sale of stock, price per share, after underwriting discounts (usd per share) \| $ / shares		$ 68.845
Public Stock Offering Pursuant to Forward Sale Agreement
Equity, Class of Treasury Stock [Line Items]
Sale of stock, number of shares issued in transaction		17,142,858

REGULATORY MATTERS (Tables)

6 Months Ended

Jun. 30, 2024

Regulated Operations [Abstract]

Schedule of Regulatory Assets


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023

Fixed-price contracts and other derivatives	$	49	$	215	$	12	$	14	$	37	$	201
Deferred income taxes recoverable in rates	1,401		1,142		700		626		615		430
Pension and PBOP plan obligations	(226)		(212)		54		48		(280)		(260)
Employee benefit costs	24		24		3		3		21		21
Removal obligations	(3,189)		(3,082)		(2,569)		(2,468)		(620)		(614)
Environmental costs	148		139		115		105		33		34
Sunrise Powerlink fire mitigation	122		124		122		124		—		—
Regulatory balancing accounts(1)(2):
Commodity – electric	(39)		(233)		(39)		(233)		—		—
Commodity – gas, including transportation	(249)		(259)		31		52		(280)		(311)
Safety and reliability	1,153		959		252		207		901		752
Public purpose programs	(424)		(273)		(189)		(144)		(235)		(129)
Wildfire mitigation plan	770		685		770		685		—		—
Liability insurance premium	110		113		83		90		27		23
Other balancing accounts	438		373		(86)		(152)		524		525
Other regulatory (liabilities) assets, net(2)	(106)		(10)		24		49		(128)		(58)
Total	$	(18)	$	(295)	$	(717)	$	(994)	$	615	$	614

(1) At June 30, 2024 and December 31, 2023, the noncurrent portion of regulatory balancing accounts – net undercollected for Sempra was $1,878 and $1,913, respectively, for SDG&E was $911 and $950, respectively, and for SoCalGas was $967 and $963, respectively.

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

Schedule of Regulatory Liabilities


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023

Fixed-price contracts and other derivatives	$	49	$	215	$	12	$	14	$	37	$	201
Deferred income taxes recoverable in rates	1,401		1,142		700		626		615		430
Pension and PBOP plan obligations	(226)		(212)		54		48		(280)		(260)
Employee benefit costs	24		24		3		3		21		21
Removal obligations	(3,189)		(3,082)		(2,569)		(2,468)		(620)		(614)
Environmental costs	148		139		115		105		33		34
Sunrise Powerlink fire mitigation	122		124		122		124		—		—
Regulatory balancing accounts(1)(2):
Commodity – electric	(39)		(233)		(39)		(233)		—		—
Commodity – gas, including transportation	(249)		(259)		31		52		(280)		(311)
Safety and reliability	1,153		959		252		207		901		752
Public purpose programs	(424)		(273)		(189)		(144)		(235)		(129)
Wildfire mitigation plan	770		685		770		685		—		—
Liability insurance premium	110		113		83		90		27		23
Other balancing accounts	438		373		(86)		(152)		524		525
Other regulatory (liabilities) assets, net(2)	(106)		(10)		24		49		(128)		(58)
Total	$	(18)	$	(295)	$	(717)	$	(994)	$	615	$	614

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

CPUC Authorized Cost of Capital and Rate Structure


AUTHORIZED COST OF CAPITAL FOR 2023

SDG&E							SoCalGas
Authorized weighting		Return on 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.

The CCM was triggered for SDG&E and SoCalGas on September 30, 2023. In December 2023, the CPUC approved increases to SDG&E’s and SoCalGas’ authorized rates of return effective January 1, 2024, which are in effect through December 31, 2025, subject to the CCM. Several parties submitted two separate requests for the CPUC to review such approval, both of which were denied.


AUTHORIZED COST OF CAPITAL FOR 2024 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.34	%	1.96	%	Long-Term Debt	45.60	%	4.54	%	2.07	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.65		5.54		Common Equity	52.00		10.50		5.46
100.00	%			7.67	%		100.00	%			7.67	%

COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2024

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 June 30, 2024, loss contingency accruals for legal matters that are probable and estimable were $52 million for Sempra, including $27 million for SoCalGas.

SDG&E

City of San Diego Franchise Agreement

In 2021, two lawsuits were filed in the California Superior Court challenging various aspects of the natural gas and electric franchise agreements granted by the City of San Diego to SDG&E. Both lawsuits ultimately sought to void the franchise agreements. In one of the cases, judgment was granted in favor of SDG&E and the City of San Diego, and the plaintiff in that case has appealed. In the second case, the court ruled in favor of SDG&E and the City of San Diego, upholding all terms of the franchise agreements, except for the two-thirds City Council vote requirement for termination if the City decides to terminate under certain circumstances. Under the court’s ruling, the City can instead terminate on a majority vote, so long as it satisfies repayment provisions under the franchise agreements. Both sides have appealed the ruling.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

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

In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) then pending against SoCalGas and Sempra related to the Leak for a payment of up to $1.8 billion. Over 99% of the Individual Plaintiffs participated and submitted valid releases, and SoCalGas paid $1.79 billion in 2022 under the agreement. The Individual Plaintiffs who did not participate in the settlement (the Non-Settling Individual Plaintiffs) are able to continue to pursue their claims. As of August 1, 2024, there are approximately 550 plaintiffs, who are either new plaintiffs or Non-Settling Individual Plaintiffs.

The new plaintiffs’ cases and Non-Settling Individual Plaintiffs’ cases are coordinated before a single court in the Los Angeles County Superior Court for pretrial management under a consolidated master complaint filed in November 2017, with one plaintiff’s case proceeding under a separate complaint. Both the consolidated master complaint and the separate complaint assert negligence, negligence per se, strict liability, negligent and intentional infliction of emotional distress and fraudulent concealment. The consolidated master complaint asserts additional causes of action for private and public nuisance (continuing and permanent), trespass, inverse condemnation, loss of consortium and wrongful death against SoCalGas and Sempra. The separate complaint asserts an additional cause of action for assault and battery. Both complaints seek compensatory and punitive damages for personal injuries, lost wages and/or lost profits, costs of future medical monitoring, and attorneys’ fees. The consolidated master complaint also seeks property damage and diminution in property value, injunctive relief and civil penalties.

At June 30, 2024, $26 million is accrued in Other Current Liabilities and $1 million is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. These accruals do not include any amounts in excess of what has been reasonably estimated to resolve certain matters that we describe above, nor any amounts that may be necessary to resolve threatened litigation, other potential litigation or other costs. We are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued, which could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Aliso Canyon Natural Gas Storage Facility Regulatory Proceeding

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

In August 2023, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting an interim range of gas inventory levels of up to 68.6 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final decision within the SB 380 OII proceeding.

At June 30, 2024, the Aliso Canyon natural gas storage facility had a net book value of $1.0 billion. If the Aliso Canyon natural gas storage facility were to be permanently closed or if future cash flows from its operation were otherwise insufficient to recover its carrying value, we may record an impairment of the facility, which could be material, and natural gas reliability and electric generation could be jeopardized.

Other Sempra

Energía Costa Azul

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

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

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

▪In a separate proceeding, the claimant filed suit to reinitiate an administrative procedure at SEDATU to obtain the property title that, as described above, had previously been issued in a ruling by the federal Agrarian Court and subsequently reversed by a federal court in Mexico. In April 2021, the proceeding in the Agrarian Court concluded with the court ordering that the administrative procedure be restarted. The administrative procedure at SEDATU may continue if SEDATU decides to reopen the matter.

In addition, the plaintiff filed a claim in the federal Agrarian Court that seeks to annul the property title for a portion of the land on which the ECA Regas Facility is situated and to obtain possession of a different parcel that allegedly overlaps with the site of the ECA Regas Facility. The proceeding, which seeks an order that SEDATU annul the ECA Regas Facility’s competing property title, was initiated in 2006 and, in July 2021, a decision was issued in favor of the ECA Regas Facility. The plaintiff appealed and, in February 2022, the appellate court confirmed the ruling in favor of the ECA Regas Facility and dismissed the appeal. The plaintiff filed a federal appeal against the appellate court ruling. 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 seeking revocation of the environmental and social impact permits issued by each of ASEA and SENER to ECA LNG authorizing natural gas liquefaction activities at the ECA Regas Facility, as follows:

▪In the first case, the court issued a provisional injunction against the permits in September 2018. In December 2018, ASEA approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility in two phases. In May 2019, the court canceled the provisional injunction. The claimant appealed the court’s decision to cancel the injunction but was not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiff and dismissed the lawsuit. The claimant appealed and the appellate court’s ruling is pending.

▪In the second case, the initial request for a provisional injunction against the permits was denied. That decision was reversed on appeal in January 2020, resulting in the issuance of a new injunction against the permits that were issued by ASEA and SENER. This injunction has uncertain application absent clarification by the court. The claimants petitioned the court to rule that construction of natural gas liquefaction facilities violated the injunction and, in February 2022, the court ruled in favor of the ECA Regas Facility, holding that the natural gas liquefaction construction activities did not violate the injunction. The claimants appealed this ruling but were not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiffs and dismissed the lawsuit. The claimants appealed and the appellate court’s ruling is pending.

▪In the third case, a group of residents filed a complaint in June 2021 against various federal and state authorities alleging deficiencies in the public consultation process for the issuance of the permits. The request for an initial injunction was denied. The claimants appealed this ruling but were not successful. The lower court’s ruling was favorable to the ECA Regas Facility, as the court determined that no harm has been caused to the plaintiffs and dismissed the lawsuit. The claimants appealed and the appellate court’s ruling is pending.

Port Arthur LNG

The PA LNG Phase 1 project holds two Clean Air Act, Prevention of Significant Deterioration permits issued by the TCEQ, which we refer to as the “2016 Permit” and the “2022 Permit.” The 2022 Permit also governs emissions for the proposed PA LNG Phase 2 project. In November 2023, a panel of the U.S. Court of Appeals for the Fifth Circuit issued a decision to vacate and remand the 2022 Permit to the TCEQ for additional explanation of the agency’s permit decision. In February 2024, the court withdrew its opinion and referred the case to the Supreme Court of Texas to resolve the question of the appropriate standard to be applied by the TCEQ. The 2022 Permit is effective during the Texas Supreme Court’s review. The 2016 Permit was not the subject of, and is unaffected by, the pending litigation of the 2022 Permit. Construction of the PA LNG Phase 1 project is proceeding uninterrupted under existing permits, and we do not currently anticipate the pending litigation to materially impact the PA LNG Phase 1 project cost, schedule or expected commercial operations at this stage.

Litigation Related to Regulatory and Other Actions by the Mexican Government

Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. The decree further purports to permit the CRE to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, if it considers them to have been obtained improperly. According to the decree, these amendments were to become effective in March 2021, and SENER, the CRE and Centro Nacional de Control de Energía (Mexico’s National Center for Energy Control) were to have 180 calendar days to modify, as necessary, all resolutions, policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. Numerous legal actions were taken against the decree, which resulted in Mexican courts issuing a suspension of the decree later in March 2021, pending resolution of such actions.

In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law. The super majority needed to find the amendment unconstitutional was not reached and the proceeding was therefore dismissed, leaving the amended Electricity Industry Law in place. However, the Court nevertheless found certain of the amendments, including the priority of dispatch for the CFE and other provisions that granted preference to the CFE over private companies, were invalid.

In January 2024, the Second Chamber of the Mexican Supreme Court definitively resolved an amparo in a separate case brought by a third party and ruled that certain provisions of the amendments of the Electricity Industry Law are unconstitutional, including the priority of dispatch for the CFE and other provisions that granted preference to the CFE over private companies. The Court also dismissed an amparo relating to the provision of the decree applicable to self-supply permits granted under the former electricity law, and established that its decision applies generally over all participants.

Sempra Infrastructure filed three lawsuits challenging the amendments to the Electricity Industry Law, including one concerning the provision permitting revocation of self-supply permits deemed improperly obtained. In each of them, Sempra Infrastructure obtained a favorable judgment in the lower court, all of which were challenged by the CRE. Following the criteria established by the Mexican Supreme Court, in July 2024, the Second Collegiate Court reversed the lower court’s decision and definitively dismissed one of the lawsuits filed by Sempra Infrastructure regarding the provision permitting revocation of self-supply permits. Consequently, the CRE may be required to seek to revoke such self-supply permits, under a legal standard that is ambiguous and not well defined under the law. Sempra Infrastructure supplies power pursuant to self-supply permits, and would be permitted to file amparos challenging the constitutionality of any such action. If such self-supply permits are revoked, it may result in increased costs for Sempra Infrastructure and for its power consumers, adversely affect our ability to develop new projects, result in decreased revenues and cash flows, and negatively impact our ability to recover the carrying values of our investments in Mexico, any of which could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects. Final resolution regarding the two remaining lawsuits is still pending in the Second Collegiate Court.

RBS Sempra Commodities – Resolved

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 The Royal Bank of Scotland plc (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS Sempra Energy Europe, a subsidiary of RBS Sempra Commodities. The claim alleged that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants were liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. In January 2024, the parties settled the Liquidating Companies’ claim against the Defendants to fully resolve the matter; our share of such settlement was approximately £7.9 million (approximately $10 million in U.S. dollars at December 31, 2023). For the year ended December 31, 2023, we recorded $40 million in equity earnings from our investment in RBS Sempra Commodities to reduce our estimate of our obligations to settle these VAT matters and related legal costs based on the settlement reached with the Liquidating Companies in January 2024.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of August 1, 2024, no lawsuits are pending. Additionally, approximately 28,000 proofs of claim were filed, but not discharged, in advance of a December 2015 deadline to file a proof of claim in the EFH bankruptcy proceeding on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. The costs to defend or resolve such claims and the amount of damages that may be incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Ordinary Course Litigation

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

LEASES

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

Lessee Accounting

We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, aircraft, 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 seven PPAs, of which SDG&E expects three will commence in 2024, three will commence in 2025, and one will commence in 2026. SDG&E expects the future minimum lease payments to be $35 million in 2024, $69 million in 2025, $90 million in 2026, $92 million in both 2027 and 2028 and $929 million thereafter (through expiration in 2041).

Sempra Infrastructure has entered into a lease agreement for tugboat services for the PA LNG Phase 1 project that it expects will commence in 2027. Sempra Infrastructure expects the future minimum lease payments to be $10 million in 2027, $12 million in 2028 and $210 million thereafter (through expiration in 2047, exclusive of certain renewal options) and total future minimum fixed payments for operation and maintenance services to be $184 million.

Lessor Accounting

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

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


LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra – Sales-type leases:
Interest income	$	2	$	1	$	3	$	3
Total revenues from sales-type leases(1)	$	2	$	1	$	3	$	3

Sempra – Operating leases:
Fixed lease payments	$	87	$	76	$	176	$	156
Variable lease payments	10		14		20		16
Total revenues from operating leases(1)	$	97	$	90	$	196	$	172

Depreciation expense	$	18	$	15	$	36	$	30

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first six months of 2024 to contractual commitments discussed in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report.

Natural Gas Contracts

SoCalGas’ natural gas contracts and transportation commitments have increased by approximately $379 million since December 31, 2023, primarily from entering into new natural gas contracts in the first six months of 2024. At June 30, 2024, we expect future payments to decrease by $1 million in 2024, and increase by $43 million in 2025, $123 million in 2026, $128 million in 2027, and $86 million in 2028 compared to December 31, 2023.

LNG Purchase Agreement

Sempra Infrastructure has an SPA for the supply of LNG to the ECA Regas Facility. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2024 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At June 30, 2024, we expect the commitment amount to decrease by $241 million in 2024, increase by $22 million in 2025, $47 million in 2026, $37 million in 2027, $14 million in 2028 and $7 million thereafter (through contract termination in 2029) compared to December 31, 2023, reflecting changes in estimated forward prices since December 31, 2023 and actual transactions for the first six months of 2024. These LNG commitment amounts are based on the assumption that all LNG cargoes under the agreement are delivered, less those already confirmed to be diverted as of June 30, 2024. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amount provided under the agreement due to the supplier electing to divert cargoes as allowed by the agreement.

ENVIRONMENTAL ISSUES

We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $44 million for Sempra, $15 million for SDG&E and $20 million for SoCalGas at June 30, 2024.

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SCG - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Net income, pretax amount, attributable to parent	$ 595	$ 790	$ 1,579	$ 2,146
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income, after tax amounts, attributable to parent	725	615	1,537	1,595
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent	5	69	48	8
Financial instruments, income tax (expense) benefit, attributable to parent	(12)	(20)	(16)	(4)
Financial instruments, net of tax amount, attributable to parent	(7)	49	32	4
Pension and other postretirement benefits, pretax amount, attributable to parent	8	2	13	(10)
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(2)	(1)	(3)	(1)
Pension and other postretirement benefits, net of tax amount, attributable to parent	6	1	10	(11)
Total other comprehensive income, pretax amount, attributable to parent	(3)	82	48	19
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(14)	(21)	(19)	(5)
Total other comprehensive income, net of tax amount, attributable to parent	(17)	61	29	14
Comprehensive income, pretax amount, attributable to parent	591	871	1,626	2,164
Comprehensive income, income tax (expense) benefit, attributable to parent	116	(196)	(61)	(556)
Comprehensive income	707	675	1,565	1,608
SoCalGas
Net income, pretax amount, attributable to parent	141	135	543	589
Income tax benefit (expense)	(10)	21	(53)	(73)
Net income, after tax amounts, attributable to parent	131	156	490	516
Other comprehensive income (loss):
Financial instruments, pretax amount, attributable to parent	1	1	1	1
Financial instruments, income tax (expense) benefit, attributable to parent	0	0	0	0
Financial instruments, net of tax amount, attributable to parent	1	1	1	1
Pension and other postretirement benefits, pretax amount, attributable to parent			1	1
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent			0	0
Pension and other postretirement benefits, net of tax amount, attributable to parent			1	1
Total other comprehensive income, pretax amount, attributable to parent	1	1	2	2
Total other comprehensive income, income tax (expense) benefit, attributable to parent	0	0	0	0
Total other comprehensive income, net of tax amount, attributable to parent	1	1	2	2
Comprehensive income, pretax amount, attributable to parent	142	136	545	591
Comprehensive income, income tax (expense) benefit, attributable to parent	(10)	21	(53)	(73)
Comprehensive income	$ 132	$ 157	$ 492	$ 518

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

Jun. 30, 2024

Dec. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Dedicated assets in support of certain benefit plans

$ 547

$ 549

^[1]

[1]	Derived from audited financial statements.

NEW ACCOUNTING STANDARDS	6 Months Ended
NEW ACCOUNTING STANDARDS	Jun. 30, 2024
Accounting Changes and Error Corrections [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDS We describe below recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures. ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures”: ASU 2023-07 revises reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, public entities are required to disclose the title and position of the CODM and explain how the CODM uses the reported measures of profit or loss to assess segment performance. The standard also requires interim disclosure of certain segment-related disclosures that previously were required only on an annual basis. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. Entities must adopt the changes to the segment reporting disclosures on a retrospective basis. We plan to adopt the standard on December 31, 2024. ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures”: ASU 2023-09 improves the transparency of income tax disclosures by requiring disaggregated information about each Registrant’s ETR reconciliation as well as information on income taxes paid. For each annual period, each Registrant will be required to disclose specific categories in the rate reconciliation and provide additional information for reconciling items that meet a quantitative threshold (if the effect of those reconciling items is equal to or greater than 5% of the amount computed by multiplying pretax income or loss by the applicable statutory income tax rate). ASU 2023-09 is effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued. We plan to adopt the standard on December 31, 2025 and are currently evaluating the effect of the standard on our financial reporting.

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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-URI https://asc.fasb.org/1943274/2147480175/815-40-65-1

Schedule of Other Ownership Interests

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	$ 40	$ 26
Derivative asset, Additional cash collateral for commodity contracts not subject to rate recovery	67	74
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	22	22
Derivative assets, Total	129	122
Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	257	77
Derivative asset, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	257	77
Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(37)	(221)
Derivative liability, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(37)	(221)
Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(12)	(5)
Derivative liability, Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(12)	(5)
Derivatives designated as hedging instruments: \| Other current assets \| Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	31	17
Derivatives designated as hedging instruments: \| Other current assets \| Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	3	0
Derivatives designated as hedging instruments: \| Other long-term assets \| Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	253	70
Derivatives designated as hedging instruments: \| Other long-term assets \| Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	0	0
Derivatives designated as hedging instruments: \| Other current liabilities \| Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	0
Derivatives designated as hedging instruments: \| Other current liabilities \| Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	(9)
Derivatives designated as hedging instruments: \| Deferred credits and other \| Interest rate instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	0
Derivatives designated as hedging instruments: \| Deferred credits and other \| Foreign exchange instruments
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	0	0
Derivatives not designated as hedging instruments: \| Other current assets \| Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	102	173
Derivative asset, subject to master netting arrangement, liability offset	(99)	(169)
Derivatives not designated as hedging instruments: \| Other current assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	9	10
Derivative asset, subject to master netting arrangement, liability offset	(6)	(5)
Associated offsetting cash collateral	0	0
Derivatives not designated as hedging instruments: \| Other long-term assets \| Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	29	52
Derivative asset, subject to master netting arrangement, liability offset	(29)	(51)
Derivatives not designated as hedging instruments: \| Other long-term assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	11	8
Derivative asset, subject to master netting arrangement, liability offset	(7)	(2)
Associated offsetting cash collateral	0	0
Derivatives not designated as hedging instruments: \| Other current liabilities \| Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(103)	(170)
Derivative liability, subject to master netting arrangement, asset offset	99	169
Derivatives not designated as hedging instruments: \| Other current liabilities \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(50)	(228)
Derivative liability, subject to master netting arrangement, asset offset	6	5
Associated offsetting cash collateral	11	12
Derivatives not designated as hedging instruments: \| Deferred credits and other \| Commodity contracts not subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(32)	(56)
Derivative liability, subject to master netting arrangement, asset offset	29	51
Derivatives not designated as hedging instruments: \| Deferred credits and other \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(16)	(9)
Derivative liability, subject to master netting arrangement, asset offset	7	2
Associated offsetting cash collateral	0	7
SDG&E \| Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	3	4
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	21	21
Derivative assets, Total	24	25
SDG&E \| Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	4	6
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	4	6
SDG&E \| Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(5)	(1)
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(5)	(1)
SDG&E \| Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	0	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	0	0
SDG&E \| Derivatives not designated as hedging instruments: \| Other current assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	7	9
Derivative asset, subject to master netting arrangement, liability offset	(4)	(5)
Associated offsetting cash collateral	0	0
SDG&E \| Derivatives not designated as hedging instruments: \| Other long-term assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	11	8
Derivative asset, subject to master netting arrangement, liability offset	(7)	(2)
Associated offsetting cash collateral	0	0
SDG&E \| Derivatives not designated as hedging instruments: \| Other current liabilities \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(20)	(18)
Derivative liability, subject to master netting arrangement, asset offset	4	5
Associated offsetting cash collateral	11	12
SDG&E \| Derivatives not designated as hedging instruments: \| Deferred credits and other \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(7)	(9)
Derivative liability, subject to master netting arrangement, asset offset	7	2
Associated offsetting cash collateral	0	7
SoCalGas \| Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	0	1
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	1	1
Derivative assets, Total	1	2
SoCalGas \| Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative asset, Net amounts presented on the balance sheet	0	0
Derivative asset, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative assets, Total	0	0
SoCalGas \| Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(28)	(210)
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(28)	(210)
SoCalGas \| Deferred credits and other
Derivatives, Fair Value [Line Items]
Derivative liability, Net amounts presented on the balance sheet	(9)	0
Derivative liability, Additional cash collateral for commodity contracts subject to rate recovery	0	0
Derivative liabilities, Total	(9)	0
SoCalGas \| Derivatives not designated as hedging instruments: \| Other current assets
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	(2)
SoCalGas \| Derivatives not designated as hedging instruments: \| Other current assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	2	1
SoCalGas \| Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	0
SoCalGas \| Derivatives not designated as hedging instruments: \| Other long-term assets \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative asset, subject to master netting arrangement, before offset	0	0
SoCalGas \| Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	2
SoCalGas \| Derivatives not designated as hedging instruments: \| Other current liabilities \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	(30)	(210)
SoCalGas \| Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives, Fair Value [Line Items]
Associated offsetting cash collateral	0
SoCalGas \| Derivatives not designated as hedging instruments: \| Deferred credits and other \| Commodity contracts subject to rate recovery
Derivatives, Fair Value [Line Items]
Derivative liability, subject to master netting arrangement, before offset	$ (9)	$ 0

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE (Tables)

6 Months Ended

Jun. 30, 2024

Earnings Per Share [Abstract]


NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI
(Dollars in millions)
	Three months ended June 30, 2023		Six months ended June 30, 2023
Sempra:
Net income attributable to Sempra	$	615	$	1,595
Transfers (to) from NCI:
Increase in shareholders’ equity for sale of NCI	—		18
Net transfers (to) from NCI	—		18
Change from net income attributable to Sempra and transfers (to) from NCI	$	615	$	1,613

Schedule of Earnings Per Share, Basic and Diluted


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Sempra:
Numerator:
Earnings attributable to common shares	$	713	$	603	$	1,514	$	1,572

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	633,450		630,014		633,135		629,926
Dilutive effect of common shares sold forward	1,139		—		906		—
Dilutive effect of stock options and RSUs(2)	1,690		2,107		1,776		2,259
Weighted-average common shares outstanding for diluted EPS	636,279		632,121		635,817		632,185

EPS:
Basic	$	1.13	$	0.96	$	2.39	$	2.50
Diluted	$	1.12	$	0.95	$	2.38	$	2.49

REVENUES

6 Months Ended

Jun. 30, 2024

Revenue from Contract with Customer [Abstract]

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

The following tables disaggregate our revenues from contracts with customers by major service line and market. We also provide a reconciliation to total revenues by segment for Sempra. The majority of our revenue is recognized over time.


DISAGGREGATED REVENUES
(Dollars in millions)
	Sempra
	Sempra California		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2024
By major service line:
Utilities	$	2,256	$	18	$	(5)	$	2,269
Energy-related businesses	—		234		(19)		215
Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484
By market:
Gas	$	1,374	$	148	$	(4)	$	1,518
Electric	882		104		(20)		966
Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484

Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484
Utilities regulatory revenues	369		—		—		369
Other revenues	—		157		1		158
Total revenues	$	2,625	$	409	$	(23)	$	3,011

	Three months ended June 30, 2023
By major service line:
Utilities	$	2,662	$	19	$	(5)	$	2,676
Energy-related businesses	—		235		(19)		216
Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892
By market:
Gas	$	1,518	$	167	$	(5)	$	1,680
Electric	1,144		87		(19)		1,212
Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892

Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892
Utilities regulatory revenues	38		—		—		38
Other revenues	—		406		(1)		405
Total revenues	$	2,700	$	660	$	(25)	$	3,335


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	Sempra
	Sempra California		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Six months ended June 30, 2024
By major service line:
Utilities	$	5,735	$	48	$	(11)	$	5,772
Energy-related businesses	—		446		(37)		409
Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181
By market:
Gas	$	3,724	$	273	$	(9)	$	3,988
Electric	2,011		221		(39)		2,193
Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181

Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181
Utilities regulatory revenues	31		—		—		31
Other revenues	—		434		5		439
Total revenues	$	5,766	$	928	$	(43)	$	6,651

	Six months ended June 30, 2023
By major service line:
Utilities	$	8,236	$	49	$	(11)	$	8,274
Energy-related businesses	—		547		(40)		507
Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781
By market:
Gas	$	5,883	$	371	$	(10)	$	6,244
Electric	2,353		225		(41)		2,537
Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781

Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781
Utilities regulatory revenues	(121)		—		—		(121)
Other revenues	—		1,260		(25)		1,235
Total revenues	$	8,115	$	1,856	$	(76)	$	9,895


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E				SoCalGas
	Three months ended June 30,
	2024		2023		2024		2023
By major service line:
Revenues from contracts with customers – Utilities	$	1,047	$	1,400	$	1,246	$	1,291
By market:
Gas	$	161	$	252	$	1,246	$	1,291
Electric	886		1,148		—		—
Revenues from contracts with customers	$	1,047	$	1,400	$	1,246	$	1,291

Revenues from contracts with customers	$	1,047	$	1,400	$	1,246	$	1,291
Utilities regulatory revenues	308		(138)		63		176
Total revenues	$	1,355	$	1,262	$	1,309	$	1,467

	Six months ended June 30,
	2024		2023		2024		2023
By major service line:
Revenues from contracts with customers – Utilities	$	2,509	$	3,165	$	3,306	$	5,132
By market:
Gas	$	491	$	806	$	3,306	$	5,132
Electric	2,018		2,359		—		—
Revenues from contracts with customers	$	2,509	$	3,165	$	3,306	$	5,132

Revenues from contracts with customers	$	2,509	$	3,165	$	3,306	$	5,132
Utilities regulatory revenues	225		(250)		(192)		129
Total revenues	$	2,734	$	2,915	$	3,114	$	5,261

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations

For contracts greater than one year, at June 30, 2024, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations for contracts greater than one year at June 30, 2024.


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2024 (excluding first six months of 2024)	$	169	$	1
2025	320		4
2026	319		4
2027	319		4
2028	252		4
Thereafter	2,304		56
Total revenues to be recognized	$	3,683	$	73

(1) Excludes intercompany transactions.

Contract Liabilities from Revenues from Contracts with Customers

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2024 or 2023. Sempra Infrastructure recorded a contract liability for funds held as collateral in lieu of a customer’s letters of credit primarily associated with its LNG storage and regasification agreement.


CONTRACT LIABILITIES
(Dollars in millions)
	2024		2023
Sempra:
Contract liabilities at January 1	$	(198)	$	(252)
Revenue from performance obligations satisfied during reporting period	3		5
Payments received in advance	(3)		(2)
Contract liabilities at June 30(1)	$	(198)	$	(249)
SDG&E:
Contract liabilities at January 1	$	(75)	$	(79)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(2)	$	(73)	$	(77)

(1) Balances at June 30, 2024 include $5 in Other Current Liabilities and $193 in Deferred Credits and Other.

(2) Balances at June 30, 2024 include $3 in Other Current Liabilities and $70 in Deferred Credits and Other.

Receivables from Revenues from Contracts with Customers

The table below shows receivable balances, net of allowances for credit losses, associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets.


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Accounts receivable – trade, net(1)	$	1,371	$	1,951
Accounts receivable – other, net	23		15
Due from unconsolidated affiliates – current(2)	6		4
Other long-term assets(3)	20		—
Total	$	1,420	$	1,970
SDG&E:
Accounts receivable – trade, net(1)	$	684	$	870
Accounts receivable – other, net	19		13
Due from unconsolidated affiliates – current(2)	8		6
Other long-term assets(3)	7		—
Total	$	718	$	889
SoCalGas:
Accounts receivable – trade, net	$	583	$	985
Accounts receivable – other, net	4		2
Other long-term assets(3)	13		—
Total	$	600	$	987

(1) At June 30, 2024 and December 31, 2023, includes $135 and $148, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

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

(3) In January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances until October 2026.

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

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

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

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

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

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

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

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

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

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

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

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

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

Revenue from Contract with Customer [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 48	$ 101	$ 201	$ 6
Pretax gain (loss) on derivatives recognized in earnings	$ 1	$ (1)	$ 1	$ 4
Natural gas
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Cost of Goods and Services Sold	Cost of Goods and Services Sold	Cost of Goods and Services Sold	Cost of Goods and Services Sold
Electric fuel and purchased power
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Cost of Goods and Services Sold	Cost of Goods and Services Sold	Cost of Goods and Services Sold	Cost of Goods and Services Sold
Interest rate instruments
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	INTEREST EXPENSE	INTEREST EXPENSE	INTEREST EXPENSE	INTEREST EXPENSE
Commodity contracts not subject to rate recovery
Derivative [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Unregulated Operating Revenue	Unregulated Operating Revenue	Unregulated Operating Revenue	Unregulated Operating Revenue
Derivatives designated as hedging instruments:
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	$ 77	$ 132	$ 248	$ 34
Pretax gain (loss) reclassified from AOCI into earnings	18	13	31	24
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	66	94	208	17
Pretax gain (loss) reclassified from AOCI into earnings	3	0	6	0
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments \| SoCalGas
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	0
Pretax gain (loss) reclassified from AOCI into earnings	(1)	(1)	(1)	(1)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	7
Pretax gain (loss) reclassified from AOCI into earnings	0	1	0	1
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	(3)	41	25	24
Pretax gain (loss) reclassified from AOCI into earnings	10	14	15	21
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	10	(1)	10	(6)
Pretax gain (loss) reclassified from AOCI into earnings	2	(1)	4	(2)
Derivatives designated as hedging instruments: \| Equity Earnings \| Fair Value Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	(7)	0	(7)	0
Pretax gain (loss) reclassified from AOCI into earnings	0	0	0	0
Derivatives designated as hedging instruments: \| Revenues: Energy- Related Businesses \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	11	(2)	12	(8)
Pretax gain (loss) reclassified from AOCI into earnings	2	0	5	0
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	(1)	1	(2)
Derivatives designated as hedging instruments: \| Other Income, Net \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings			0	6
Derivatives not designated as hedging instruments:
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	24	206	74	590
Derivatives not designated as hedging instruments: \| Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	41	253	120	702
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| SoCalGas
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(21)	(20)	(27)	(47)
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| SDG&E
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	4	(27)	(19)	(18)
Derivatives not designated as hedging instruments: \| Contingent Interest Rate Derivative
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	0	(47)
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	(21)	(20)	(27)	(47)
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	$ 4	$ (27)	$ (19)	$ (18)

REVENUES (Tables)

6 Months Ended

Jun. 30, 2024

Schedule of Disaggregation of Revenue


DISAGGREGATED REVENUES
(Dollars in millions)
	Sempra
	Sempra California		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2024
By major service line:
Utilities	$	2,256	$	18	$	(5)	$	2,269
Energy-related businesses	—		234		(19)		215
Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484
By market:
Gas	$	1,374	$	148	$	(4)	$	1,518
Electric	882		104		(20)		966
Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484

Revenues from contracts with customers	$	2,256	$	252	$	(24)	$	2,484
Utilities regulatory revenues	369		—		—		369
Other revenues	—		157		1		158
Total revenues	$	2,625	$	409	$	(23)	$	3,011

	Three months ended June 30, 2023
By major service line:
Utilities	$	2,662	$	19	$	(5)	$	2,676
Energy-related businesses	—		235		(19)		216
Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892
By market:
Gas	$	1,518	$	167	$	(5)	$	1,680
Electric	1,144		87		(19)		1,212
Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892

Revenues from contracts with customers	$	2,662	$	254	$	(24)	$	2,892
Utilities regulatory revenues	38		—		—		38
Other revenues	—		406		(1)		405
Total revenues	$	2,700	$	660	$	(25)	$	3,335


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	Sempra
	Sempra California		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Six months ended June 30, 2024
By major service line:
Utilities	$	5,735	$	48	$	(11)	$	5,772
Energy-related businesses	—		446		(37)		409
Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181
By market:
Gas	$	3,724	$	273	$	(9)	$	3,988
Electric	2,011		221		(39)		2,193
Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181

Revenues from contracts with customers	$	5,735	$	494	$	(48)	$	6,181
Utilities regulatory revenues	31		—		—		31
Other revenues	—		434		5		439
Total revenues	$	5,766	$	928	$	(43)	$	6,651

	Six months ended June 30, 2023
By major service line:
Utilities	$	8,236	$	49	$	(11)	$	8,274
Energy-related businesses	—		547		(40)		507
Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781
By market:
Gas	$	5,883	$	371	$	(10)	$	6,244
Electric	2,353		225		(41)		2,537
Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781

Revenues from contracts with customers	$	8,236	$	596	$	(51)	$	8,781
Utilities regulatory revenues	(121)		—		—		(121)
Other revenues	—		1,260		(25)		1,235
Total revenues	$	8,115	$	1,856	$	(76)	$	9,895


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E				SoCalGas
	Three months ended June 30,
	2024		2023		2024		2023
By major service line:
Revenues from contracts with customers – Utilities	$	1,047	$	1,400	$	1,246	$	1,291
By market:
Gas	$	161	$	252	$	1,246	$	1,291
Electric	886		1,148		—		—
Revenues from contracts with customers	$	1,047	$	1,400	$	1,246	$	1,291

Revenues from contracts with customers	$	1,047	$	1,400	$	1,246	$	1,291
Utilities regulatory revenues	308		(138)		63		176
Total revenues	$	1,355	$	1,262	$	1,309	$	1,467

	Six months ended June 30,
	2024		2023		2024		2023
By major service line:
Revenues from contracts with customers – Utilities	$	2,509	$	3,165	$	3,306	$	5,132
By market:
Gas	$	491	$	806	$	3,306	$	5,132
Electric	2,018		2,359		—		—
Revenues from contracts with customers	$	2,509	$	3,165	$	3,306	$	5,132

Revenues from contracts with customers	$	2,509	$	3,165	$	3,306	$	5,132
Utilities regulatory revenues	225		(250)		(192)		129
Total revenues	$	2,734	$	2,915	$	3,114	$	5,261

Schedule of Timing of Remaining Performance Obligations


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2024 (excluding first six months of 2024)	$	169	$	1
2025	320		4
2026	319		4
2027	319		4
2028	252		4
Thereafter	2,304		56
Total revenues to be recognized	$	3,683	$	73

(1) Excludes intercompany transactions.

Schedule of Contract Liabilities


CONTRACT LIABILITIES
(Dollars in millions)
	2024		2023
Sempra:
Contract liabilities at January 1	$	(198)	$	(252)
Revenue from performance obligations satisfied during reporting period	3		5
Payments received in advance	(3)		(2)
Contract liabilities at June 30(1)	$	(198)	$	(249)
SDG&E:
Contract liabilities at January 1	$	(75)	$	(79)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(2)	$	(73)	$	(77)

(1) Balances at June 30, 2024 include $5 in Other Current Liabilities and $193 in Deferred Credits and Other.

(2) Balances at June 30, 2024 include $3 in Other Current Liabilities and $70 in Deferred Credits and Other.

Schedule of Contract Accounts Receivable

The table below shows receivable balances, net of allowances for credit losses, associated with revenues from contracts with customers on the Condensed Consolidated Balance Sheets.


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2024		December 31, 2023
Sempra:
Accounts receivable – trade, net(1)	$	1,371	$	1,951
Accounts receivable – other, net	23		15
Due from unconsolidated affiliates – current(2)	6		4
Other long-term assets(3)	20		—
Total	$	1,420	$	1,970
SDG&E:
Accounts receivable – trade, net(1)	$	684	$	870
Accounts receivable – other, net	19		13
Due from unconsolidated affiliates – current(2)	8		6
Other long-term assets(3)	7		—
Total	$	718	$	889
SoCalGas:
Accounts receivable – trade, net	$	583	$	985
Accounts receivable – other, net	4		2
Other long-term assets(3)	13		—
Total	$	600	$	987

(1) At June 30, 2024 and December 31, 2023, includes $135 and $148, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

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

(3) In January 2024, the CPUC directed SDG&E and SoCalGas to offer long-term repayment plans to eligible residential customers with past-due balances until October 2026.

CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,752	$ 1,908
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,197	1,088
Deferred income taxes and investment tax credits	(34)	323
Bad debt expense	94	220
Other	(5)	(19)
Net change in working capital components	(99)	1,474
Changes in other noncurrent assets and liabilities, net	(78)	(514)
Net cash provided by operating activities	2,520	3,737
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,830)	(4,282)
Purchases of nuclear decommissioning trust assets	(401)	(322)
Proceeds from sales of nuclear decommissioning trust assets	442	356
Other	8	11
Net cash used in investing activities	(4,168)	(4,421)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	3,812	5,614
Payments on debt (maturities greater than 90 days) and finance leases	(1,197)	(3,392)
(Decrease) increase in short-term debt, net	(817)	(388)
Net cash provided by financing activities	1,618	1,457
(Decrease) increase in cash, cash equivalents and restricted cash	(38)	780
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, June 30	351	1,242
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	574	612
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	885	863
Increase in finance lease obligations for investment in PP&E	12	36
Increase in ARO for investment in PP&E	(2)	(46)
SDG&E
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	409	442
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	602	530
Deferred income taxes and investment tax credits	51	(31)
Bad debt expense	24	60
Other	(19)	(29)
Net change in working capital components	(28)	235
Changes in other noncurrent assets and liabilities, net	17	(241)
Net cash provided by operating activities	1,056	966
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,234)	(1,239)
Purchases of nuclear decommissioning trust assets	(362)	(265)
Proceeds from sales of nuclear decommissioning trust assets	380	294
Other	10	10
Net cash used in investing activities	(1,206)	(1,200)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	594	792
Payments on debt (maturities greater than 90 days) and finance leases	(422)	(19)
(Decrease) increase in short-term debt, net	0	(205)
Debt issuance costs	(6)	(9)
Net cash provided by financing activities	166	559
(Decrease) increase in cash, cash equivalents and restricted cash	16	325
Cash, cash equivalents and restricted cash, January 1	50	7
Cash, cash equivalents and restricted cash, June 30	66	332
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	249	224
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	188	233
Increase in finance lease obligations for investment in PP&E	2	4
Increase in ARO for investment in PP&E	$ 0	$ 10

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	6 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	Jun. 30, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities, which invest in, develop and operate energy infrastructure in North America, and provide electric and gas services to customers. Sempra has three separate reportable segments, which we describe in Note 12. In the fourth quarter of 2023, Sempra realigned its reportable segments to reflect changes in how the CODM oversees our three platforms: Sempra California, Sempra Texas Utilities and Sempra Infrastructure. Our former SDG&E and SoCalGas reportable segments were combined into one operating and reportable segment, Sempra California, which is consistent with how the CODM assesses performance due to the similarities of their operations, including geographic location and regulatory framework in California. Sempra’s historical segment disclosures have been restated to conform with the current presentation, so that all discussions reflect the revised segment information of its three reportable segments. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SDG&E is a regulated public utility that provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. SDG&E has one reportable segment. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra. SoCalGas is a regulated public natural gas distribution utility, serving customers throughout most of Southern California and part of central California. SoCalGas has one reportable segment.
Basis of Presentation	BASIS OF PRESENTATION This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. We have eliminated intercompany accounts and transactions within the condensed consolidated financial statements of each Registrant. We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2024 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. All December 31, 2023 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2023 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes. The information contained in this report should be read in conjunction with the Annual Report.
Regulated Operations	REGULATED OPERATIONS SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas. Our Sempra Infrastructure segment includes the operating companies of our subsidiary, SI Partners, as well as certain holding companies and risk management activity. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP.
Variable Interest Entity	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess: ▪the purpose and design of the VIE; ▪the nature of the VIE’s risks and the risks we absorb; ▪the power to direct activities that most significantly impact the economic performance of the VIE; and ▪the obligation to absorb losses or the right to receive benefits that could be significant to the VIE. 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.
Credit Losses	CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in sales-type leases and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 5. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered.
Interim Period Effective Tax Rate	Sempra, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted ETR anticipated for the full year. Unusual and infrequent items and items that cannot be reliably estimated are recorded in the interim period in which they occur, which can result in variability in the ETR.
Flow-Through Rate-Making Treatment Tax	For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment: ▪repairs expenditures related to a certain portion of utility plant fixed assets ▪the equity portion of AFUDC, which is non-taxable ▪a portion of the cost of removal of utility plant assets ▪utility self-developed software expenditures ▪depreciation on a certain portion of utility plant assets ▪state income taxes AFUDC related to equity recorded for regulated construction projects at Sempra Infrastructure has similar flow-through treatment. Under the IRA, in 2023, the scope of projects eligible for ITCs was expanded to include standalone energy storage projects, which are transferable under the IRA. The IRA also provided an election through 2024 that permits ITCs related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset. In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the three months and six months ended June 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. Sempra intends to elect this change in tax accounting method in its consolidated 2023 income tax return filing, and Sempra, SDG&E and SoCalGas have applied this methodology in the calculation of their 2024 forecasted ETRs. Sempra, SDG&E, and SoCalGas record regulatory liabilities for benefits that will be flowed through to customers in the future.
Derivative Financial Instruments	HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk of variability of future cash flows of a given revenue or expense item, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power. ▪SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. ▪Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations. ▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other derivatives to hedge exposures such as GHG allowances. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. FOREIGN CURRENCY DERIVATIVES We may utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican fixed interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. In May 2024, Oncor entered into cross-currency swaps designated as fair value hedges intended to offset foreign currency exchange rate risk related to its Euro-denominated debt. We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. CREDIT RISK RELATED CONTINGENT FEATURES For Sempra, SDG&E and SoCalGas, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. 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	We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2023. 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 at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” ▪Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). ▪As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Other Sempra.” 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 Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Other Sempra Fair Value of Financial Instruments 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.
Earnings Per Common Share	EARNINGS PER COMMON SHARE Basic EPS is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. 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.
Gains and Losses on NDTs	Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Legal Proceedings	LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.
Segment Information	Sempra has three separately managed reportable segments, as follows: ▪Sempra California provides natural gas and electric service to Southern California and part of central California through Sempra’s wholly owned subsidiaries, SDG&E and SoCalGas. ▪Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns a 70% interest in SI Partners. The cost of common services shared by the business segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NET INCOME ATTRIBUTABLE TO SEMPRA AND TRANSFERS (TO) FROM NCI (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Earnings Per Share [Abstract]
Net income attributable to Sempra	$ 725	$ 615	$ 1,537	$ 1,595
Increase in shareholders’ equity for sale of NCI		0		18
Net transfers (to) from NCI		0		18
Change from net income attributable to Sempra and transfers (to) from NCI		$ 615		$ 1,613

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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REGULATORY MATTERS - CPUC GRC Narrative (Details) $ in Millions	1 Months Ended		12 Months Ended
	Oct. 31, 2023 USD ($)	May 31, 2022 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Jun. 30, 2024 request
General Rate Case [Line Items]
Number of CPUC requests \| request					2
2024 GRC - 2024 Requirement \| SDG&E \| General Rate Case
General Rate Case [Line Items]
Requested revenue requirements		$ 3,000
Requested review and recovery of wildfire mitigation plan	$ 1,500
2024 GRC - 2024 Requirement \| SDG&E \| General Rate Case \| Forecast
General Rate Case [Line Items]
General rate case, expected recovery of wildlife mitigation plan costs			$ 96
2024 GRC - 2024 Requirement \| SDG&E \| General Rate Case \| Subsequent Event \| Forecast
General Rate Case [Line Items]
General rate case, expected recovery of wildlife mitigation plan costs				$ 194
2024 GRC - 2024 Requirement \| SDG&E \| General Rate Case \| Minimum
General Rate Case [Line Items]
Estimate of annual increases		8.00%
2024 GRC - 2024 Requirement \| SDG&E \| General Rate Case \| Maximum
General Rate Case [Line Items]
Estimate of annual increases		11.00%
2024 GRC - 2024 Requirement \| SoCalGas \| General Rate Case
General Rate Case [Line Items]
Requested revenue requirements		$ 4,400
2024 GRC - 2024 Requirement \| SoCalGas \| General Rate Case \| Minimum
General Rate Case [Line Items]
Estimate of annual increases		6.00%
2024 GRC - 2024 Requirement \| SoCalGas \| General Rate Case \| Maximum
General Rate Case [Line Items]
Estimate of annual increases		8.00%

Insider Trading Arrangements

3 Months Ended

6 Months Ended

Jun. 30, 2024

Material Terms of Trading Arrangement

During the most recent fiscal quarter, (i) the individual listed below, who was at the time a Sempra director or officer, adopted a Rule 10b5-1 trading arrangement with respect to the securities of Sempra, with the material terms described below; (ii) no Sempra directors or officers terminated a Rule 10b5-1 trading arrangement or adopted or terminated a non-Rule 10b5-1 trading arrangement with respect to the securities of Sempra; and (iii) no SDG&E or SoCalGas directors or officers adopted or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement with respect to the securities of each such Registrant. As used herein, directors and officers are as defined in Rule 16a-1(f) under the Exchange Act, a Rule 10b5-1 trading arrangement is as defined in Item 408(a) of SEC Regulation S-K, and a non-Rule 10b5-1 trading arrangement is as defined in Item 408(c) of SEC Regulation S-K. The Rule 10b5-1 trading arrangement listed below is intended to satisfy the affirmative defense of Rule 10b5-1(c) under the Exchange Act.


RULE 10B5-1 TRADING ARRANGEMENT
(In the three months ended June 30, 2024)
Name and title of the director or officer	Date on which the director or officer adopted or terminated the trading arrangement	Duration of the trading arrangement	Aggregate number of securities to be purchased or sold pursuant to the trading arrangement
Sempra:
Diana L. Day, Chief Legal Counsel	May 20, 2024	From May 14, 2025 until all shares are sold or the trading arrangement is otherwise terminated	▪2,875 shares of Sempra common stock subject to time-based RSUs vesting in January 2025, plus the accumulated dividend equivalents related to such RSUs ▪2,038 shares of Sempra common stock subject to time-based RSUs vesting in January 2026, plus the accumulated dividend equivalents related to such RSUs ▪all shares of Sempra common stock subject to 5,009 performance-based RSUs vesting in January and February of 2025(1) ▪all shares of Sempra common stock subject to 4,939 performance-based RSUs vesting in January and February of 2026(1) in each case (i) plus shares subject to any additional awards of time-based RSUs that may be granted to Ms. Day after the date hereof and that vest at the times set forth above, and (ii) less shares to which Ms. Day would otherwise be entitled that are withheld to satisfy minimum statutory tax withholding requirements

(1) Shares subject to the performance-based RSUs scheduled to vest in January and February of 2025 and 2026 generally will vest, in whole or in part, or be forfeited in early 2025 or early 2026, as applicable, based on our total shareholder return for the three-year performance period ending on January 2, 2025 and January 2, 2026, as applicable, and EPS growth (as adjusted for long-term incentive plan purposes) for the three-year performance period ending on December 31, 2024 and December 31, 2025, as applicable. The number of shares that will vest may range from 0% to 200% of the target number of shares (plus dividend equivalents) and cannot be ascertained until the performance period has ended and the Compensation and Talent Development Committee of Sempra’s board of directors has certified the results.

Non-Rule 10b5-1 Arrangement Adopted

false

Rule 10b5-1 Arrangement Terminated

false

Non-Rule 10b5-1 Arrangement Terminated

false

Diana L. Day [Member]

Rule 10b5-1 Arrangement Adopted

Name

Diana L. Day

Title

Chief Legal Counsel

true

Adoption Date

May 20, 2024

Sempra Common Stock Subject To Time-Based RSUs Vesting In 2025 [Member] | Diana L. Day [Member]

Sempra Common Stock Subject To Time-Based RSUs Vesting In 2026 [Member] | Diana L. Day [Member]

2,875

Sempra Common Stock Subject To Performance-Based RSUs Vesting In 2025 [Member] | Diana L. Day [Member]

2,038

Sempra Common Stock Subject To Performance-Based RSUs Vesting In 2026 [Member] | Diana L. Day [Member]

5,009

4,939

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - SDG&E - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Jointly Owned Utility Plant Interests [Line Items]
Nuclear liability insurance coverage, maximum	$ 500
Secondary financial protection, maximum	60
Secondary financial protection, company contribution, annual maximum	560
Nuclear property damage insurance	130
Federal nuclear property damage insurance, minimum required	50
Nuclear property insurance terrorism coverage, maximum	$ 3,240
Jointly Owned Nuclear Power Plant
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20.00%
Percent of dismantlement work expense (as a percent)	20.00%
Decommissioning costs	$ 497
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 79

SEMPRA - EQUITY AND EARNINGS PER COMMON SHARE - NCI NARRATIVE (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Noncontrolling Interest [Line Items]
Contributions		$ 312	$ 498	$ 786	$ 595
Sale					$ 255
Port Arthur LNG
Noncontrolling Interest [Line Items]
Contributions	$ 237
Indirect Subsidiary Of SI Partners \| Port Arthur LNG
Noncontrolling Interest [Line Items]
Cash consideration	265
Sale	18
Sale of noncontrolling interest, transaction costs	3
Sale of noncontrolling interest, tax impacts	7
Funding commitment, aggregate amount	$ 9,000
Funding commitment paid		$ 2,400		$ 2,400
Port Arthur LNG \| Indirect Subsidiary Of SI Partners
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	30.00%
Funding commitment (in percent)	110.00%
Guaranteed funding amount (in percent)	70.00%

SEMPRA - SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2024

Segment Reporting [Abstract]

Segment Information

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


SEGMENT INFORMATION
(Dollars in millions)
	June 30, 2024		December 31, 2023
ASSETS
Sempra California	$	54,462	$	53,430
Sempra Texas Utilities	14,940		14,392
Sempra Infrastructure	21,131		19,430
All other	963		967
Intersegment receivables	(1,023)		(1,038)
Total	$	90,473	$	87,181
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities	$	14,927	$	14,380
Sempra Infrastructure	2,286		2,129
All other	1		1
Total	$	17,214	$	16,510

	Six months ended June 30,
	2024		2023
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
Sempra California	$	2,212	$	2,200
Sempra Infrastructure	1,617		2,078
All other	1		4
Total	$	3,830	$	4,282


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
REVENUES
Sempra California	$	2,625	$	2,700	$	5,766	$	8,115
Sempra Infrastructure	409		660		928		1,856

Adjustments and eliminations	1		(2)		—		(2)
Intersegment revenues(1)	(24)		(23)		(43)		(74)
Total	$	3,011	$	3,335	$	6,651	$	9,895
DEPRECIATION AND AMORTIZATION
Sempra California	$	528	$	476	$	1,049	$	944
Sempra Infrastructure	73		70		145		139
All other	2		3		3		5
Total	$	603	$	549	$	1,197	$	1,088
INTEREST INCOME
Sempra California	$	5	$	5	$	8	$	10
Sempra Infrastructure	7		6		12		21
All other	6		6		11		10
Intercompany eliminations	(1)		—		(1)		—
Total	$	17	$	17	$	30	$	41
INTEREST EXPENSE
Sempra California	$	209	$	194	$	414	$	381
Sempra Infrastructure	—		25		—		120
All other	103		99		203		183
Intercompany eliminations	(1)		(1)		(1)		(1)
Total	$	311	$	317	$	616	$	683
INCOME TAX EXPENSE (BENEFIT)
Sempra California	$	44	$	(17)	$	127	$	84
Sempra Infrastructure	(133)		201		(24)		531
All other	(41)		(9)		(61)		(64)
Total	$	(130)	$	175	$	42	$	551
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	2	$	4	$	3
Sempra Infrastructure	158		151		290		282
	160		153		294		285
Equity earnings, net of income tax:
Sempra Texas Utilities	202		160		385		243
Sempra Infrastructure	71		75		102		79
	273		235		487		322
Total	$	433	$	388	$	781	$	607
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
Sempra California	$	316	$	339	$	898	$	957
Sempra Texas Utilities	202		160		385		243
Sempra Infrastructure	291		208		422		523
All other	(96)		(104)		(191)		(151)
Total	$	713	$	603	$	1,514	$	1,572

(1) Revenues for reportable segments include intersegment revenues of $5 and $19 for the three months ended June 30, 2024 and $10 and $33 for the six months ended June 30, 2024; $4 and $19 for the three months ended June 30, 2023 and $9 and $65 for the six months ended June 30, 2023 for Sempra California and Sempra Infrastructure, respectively.

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE AND FOREIGN CURRENCY DERIVATIVES (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Foreign currency derivatives
Derivative [Line Items]
Notional amount of derivative	$ 104	$ 176
Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Notional amount of derivative	4,448	4,451
Cash Flow Hedging \| Interest Rate Swap
Derivative [Line Items]
Notional amounts	$ 881	$ 488

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

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Comprehensive Income [Abstract]
Net income, pretax amount, attributable to parent	$ 595	$ 790	$ 1,579	$ 2,146
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income, after tax amounts, attributable to parent	725	615	1,537	1,595
Net income, Non-controlling interest (after tax)	146	121	215	313
Net income	871	736	1,752	1,908
Foreign currency translation adjustments
Foreign currency translation adjustments, pretax amount, attributable to parent	(16)	11	(13)	21
Foreign currency translation adjustments, income tax (expense) benefit, attributable to parent	0	0	0	0
Foreign currency translation adjustments, net of tax amount, attributable to parent	(16)	11	(13)	21
Foreign currency translation adjustments, net of tax amount, attributable to noncontrolling interests	(7)	4	(6)	8
Total foreign currency translation adjustments	(23)	15	(19)	29
Financial instruments
Financial instruments, pretax amount, attributable to parent	5	69	48	8
Financial instruments, income tax (expense) benefit, attributable to parent	(12)	(20)	(16)	(4)
Financial instruments, net of tax amount, attributable to parent	(7)	49	32	4
Financial instruments, after tax amount, attributable to noncontrolling interests	55	52	169	2
Pretax gain (loss) reclassified from AOCI into earnings	48	101	201	6
Pension and other postretirement benefits
Pension and other postretirement benefits, pretax amount, attributable to parent	8	2	13	(10)
Pension and other postretirement benefits, income tax (expense) benefit, attributable to parent	(2)	(1)	(3)	(1)
Pension and other postretirement benefits, net of tax amount, attributable to parent	6	1	10	(11)
Pension and other postretirement benefits, net of tax amount, attributable to noncontrolling interests	0	0	0	0
Total pension and other postretirement benefits	6	1	10	(11)
Total other comprehensive income, pretax amount, attributable to parent	(3)	82	48	19
Total other comprehensive income, income tax (expense) benefit, attributable to parent	(14)	(21)	(19)	(5)
Total other comprehensive income, net of tax amount, attributable to parent	(17)	61	29	14
Total other comprehensive income, net of tax amount, attributable to noncontrolling interests	48	56	163	10
Total other comprehensive (loss) income	31	117	192	24
Comprehensive income, pretax amount, attributable to parent	592	872	1,627	2,165
Comprehensive income, income tax (expense) benefit, attributable to parent	116	(196)	(61)	(556)
Comprehensive income, net of tax amount, attributable to parent	708	676	1,566	1,609
Comprehensive income, net of tax amount, attributable to noncontrolling interests	194	177	378	323
Total comprehensive income	902	853	1,944	1,932
Preferred dividends of subsidiary, pretax amount, attributable to parent	(1)	(1)	(1)	(1)
Preferred dividends of subsidiary, income tax (expense) benefit, attributable to parent	0	0	0	0
Preferred dividends of subsidiary, net of tax amount, attributable to parent	(1)	(1)	(1)	(1)
Preferred dividends of subsidiary, net of tax amount, attributable to noncontrolling interests	0	0	0	0
Total preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income, pretax amount, attributable to parent	591	871	1,626	2,164
Comprehensive income, income tax (expense) benefit, attributable to parent	116	(196)	(61)	(556)
Comprehensive income	707	675	1,565	1,608
Comprehensive income, net of tax amount, attributable to noncontrolling interest	194	177	378	323
Total comprehensive income	$ 901	$ 852	$ 1,943	$ 1,931

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES NARRATIVE (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Derivative [Line Items]
Derivative fair value	$ 44	$ 215
Collateral	44
SoCalGas
Derivative [Line Items]
Derivative fair value	37	$ 210
Collateral	$ 37

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,752	$ 1,908
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,197	1,088
Deferred income taxes and investment tax credits	(34)	323
Equity earnings	(781)	(607)
Share-based compensation expense	41	31
Fixed-price contracts and other derivatives	28	(569)
Bad debt expense	94	220
Other	(5)	(19)
Net change in working capital components	(99)	1,474
Distributions from investments	405	402
Changes in other noncurrent assets and liabilities, net	(78)	(514)
Net cash provided by operating activities	2,520	3,737
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,830)	(4,282)
Expenditures for investments	(387)	(184)
Purchases of nuclear decommissioning and other trust assets	(401)	(322)
Proceeds from sales of nuclear decommissioning and other trust assets	442	356
Other	8	11
Net cash used in investing activities	(4,168)	(4,421)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(741)	(734)
Preferred dividends paid	(22)	(22)
Issuances of common stock	18	0
Repurchases of common stock	(40)	(31)
Issuances of debt (maturities greater than 90 days)	3,812	5,614
Payments on debt (maturities greater than 90 days) and finance leases	(1,197)	(3,392)
Decrease in short-term debt, net	(817)	(388)
Advances from unconsolidated affiliates	45	14
Proceeds from sale of noncontrolling interests	0	265
Distributions to noncontrolling interests	(203)	(252)
Contributions from noncontrolling interests	786	543
Settlement of cross-currency swaps	0	(99)
Other	(23)	(61)
Net cash provided by financing activities	1,618	1,457
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(8)	7
(Decrease) increase in cash, cash equivalents and restricted cash	(38)	780
Cash, cash equivalents and restricted cash, January 1	389	462
Cash, cash equivalents and restricted cash, June 30	351	1,242
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	574	612
Income tax payments, net of refunds	233	120
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Repayments of advances from unconsolidated affiliate in lieu of distributions	62	36
Accrued capital expenditures	885	863
Increase in finance lease obligations for investment in PP&E	12	36
Decrease in ARO for investment in PP&E	(2)	(46)
Common dividends issued in stock	27	0
Contributions from NCI	0	186
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	$ 393	$ 375

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

Jun. 30, 2024

Dec. 31, 2023

$ 228

$ 236

^[1]

1,552

2,151

^[1]

441

561

^[1]

^[1]

Income taxes receivable

^[1]

467

482

^[1]

Prepaid expenses

173

273

^[1]

226

^[1]

1,176

1,189

^[1]

^[1]

4,378

5,470

^[1]

4,011

3,771

^[1]

Nuclear decommissioning trusts

769

301

^[1]

882

872

^[1]

711

723

^[1]

Wildfire fund

272

269

^[1]

1,857

1,603

^[1]

28,411

26,751

^[1]

75,923

72,495

^[1]

(18,239)

(17,535)

^[1]

57,684

54,960

^[1]

90,473

87,181

^[1]

378

526

^[1]

Current portion of long-term debt and finance leases

125

553

^[1]

1,711

975

^[1]

1,176

1,189

^[1]

9,540

10,090

^[1]

28,966

27,759

^[1]

3,959

3,739

^[1]

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

334

^[1]

405

407

^[1]

5,486

5,254

^[1]

3,689

3,642

^[1]

2,373

2,329

^[1]

16,548

15,678

^[1]

^[1]

Equity:

12,250

12,204

^[1]

16,461

15,732

^[1]

(121)

(150)

^[1]

29,479

28,675

^[1]

90,473

87,181

^[1]

Related Party

^[1]

Nonrelated Party

1,202

1,374

^[1]

^[1]

684

870

^[1]

119

141

^[1]

^[1]

Income taxes receivable

212

236

^[1]

159

153

^[1]

Prepaid expenses

165

^[1]

^[1]

158

^[1]

^[1]

1,541

1,823

^[1]

2,014

1,968

^[1]

Nuclear decommissioning trusts

269

202

^[1]

882

872

^[1]

358

368

^[1]

Wildfire fund

272

269

^[1]

151

134

^[1]

3,946

3,813

^[1]

31,918

30,918

^[1]

(7,668)

(7,369)

^[1]

24,250

23,549

^[1]

29,737

29,185

^[1]

Accounts payable

742

808

^[1]

Interest payable

^[1]

102

145

^[1]

Deferred capacity sales

202

^[1]

Accrued franchise fees

112

^[1]

Current portion of long-term debt and finance leases

447

^[1]

441

^[1]

158

^[1]

122

116

^[1]

1,856

2,597

^[1]

10,026

9,453

^[1]

2,662

2,534

^[1]

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

^[1]

^[1]

2,993

2,873

^[1]

773

778

^[1]

990

969

^[1]

7,544

7,233

^[1]

^[1]

Equity:

Preferred stock

^[1]

1,660

^[1]

8,659

8,250

^[1]

(8)

^[1]

10,311

9,902

^[1]

29,737

29,185

^[1]

SDG&E | Related Party

^[1]

SDG&E | Nonrelated Party

SEMPRA - SEGMENT INFORMATION

$ 229

$ 216

^[1]

[1]	Derived from audited financial statements.

REGULATORY MATTERS

6 Months Ended

Jun. 30, 2024

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY ASSETS AND LIABILITIES

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


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023

Fixed-price contracts and other derivatives	$	49	$	215	$	12	$	14	$	37	$	201
Deferred income taxes recoverable in rates	1,401		1,142		700		626		615		430
Pension and PBOP plan obligations	(226)		(212)		54		48		(280)		(260)
Employee benefit costs	24		24		3		3		21		21
Removal obligations	(3,189)		(3,082)		(2,569)		(2,468)		(620)		(614)
Environmental costs	148		139		115		105		33		34
Sunrise Powerlink fire mitigation	122		124		122		124		—		—
Regulatory balancing accounts(1)(2):
Commodity – electric	(39)		(233)		(39)		(233)		—		—
Commodity – gas, including transportation	(249)		(259)		31		52		(280)		(311)
Safety and reliability	1,153		959		252		207		901		752
Public purpose programs	(424)		(273)		(189)		(144)		(235)		(129)
Wildfire mitigation plan	770		685		770		685		—		—
Liability insurance premium	110		113		83		90		27		23
Other balancing accounts	438		373		(86)		(152)		524		525
Other regulatory (liabilities) assets, net(2)	(106)		(10)		24		49		(128)		(58)
Total	$	(18)	$	(295)	$	(717)	$	(994)	$	615	$	614

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

CPUC GRC

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

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, if adopted, are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. We expect the CPUC to issue a proposed decision in the third quarter of 2024 and a final decision by the end of this year. The CPUC has authorized SDG&E and SoCalGas to recognize the effects of the 2024 GRC final decision retroactive to January 1, 2024.

SDG&E and SoCalGas recorded CPUC-authorized base revenues in the six months ended June 30, 2024 based on 2023 levels authorized under the 2019 GRC because a final decision in the 2024 GRC remains pending. The results of the 2024 GRC may materially differ from what is contained in the GRC applications.

2024 GRC Track 2

In October 2023, SDG&E submitted a separate request to the CPUC in its 2024 GRC, known as a Track 2 request. This request seeks review and recovery of $1.5 billion of wildfire mitigation plan costs incurred from 2019 through 2022 that were in addition to amounts authorized in the 2019 GRC. SDG&E expects to receive a proposed reasonableness review decision for Track 2 in the first quarter of 2025.

Revenues associated with the Track 2 amounts described above have been recorded in a regulatory account. In February 2024, the CPUC approved an interim cost recovery mechanism that would permit SDG&E to recover in rates $194 million and $96 million of this regulatory account balance in 2024 and 2025, respectively. Such recovery of SDG&E’s wildfire mitigation plan regulatory account balance will be subject to refund, contingent on the reasonableness review decision for Track 2.

2024 GRC Track 3

SDG&E expects to submit in late 2024 an additional request to the CPUC in its 2024 GRC, known as a Track 3 request, for review and recovery of its 2023 wildfire mitigation plan costs.

CPUC COST OF CAPITAL

The CPUC approved the following cost of capital for SDG&E and SoCalGas that became effective on January 1, 2023 and was to remain in effect through December 31, 2025, subject to the CCM. The CPUC has issued a ruling to initiate a second phase of this cost of capital proceeding to evaluate potential modifications to the CCM. We expect a proposed decision on the second phase in the second half of 2024.


AUTHORIZED COST OF CAPITAL FOR 2023

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.


AUTHORIZED COST OF CAPITAL FOR 2024 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.34	%	1.96	%	Long-Term Debt	45.60	%	4.54	%	2.07	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.65		5.54		Common Equity	52.00		10.50		5.46
100.00	%			7.67	%		100.00	%			7.67	%

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). In June 2024, SDG&E exercised its right to terminate the TO5 settlement. SDG&E expects to file with the FERC in the fourth quarter of 2024 a new rate request to be effective January 1, 2025. In May 2024, the CPUC and other parties filed a petition and complaint with the FERC seeking an order that directs SDG&E to remove the California ISO adder from its current TO5 formula rate and refund the California ISO adder retroactively from June 1, 2019. SDG&E expects further proceedings on these two matters.

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 be completed around 2030. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal. SDG&E is responsible for approximately 20% of the total decommissioning cost.

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

Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In December 2023, the CPUC granted SDG&E authorization to access NDT funds of up to $79 million for forecasted 2024 costs.

Nuclear Decommissioning Trusts

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


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2024
Short-term investments, primarily cash equivalents	$	23	$	—	$	—	$	23
Equity securities	90		235		(4)		321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	61		1		(1)		61
Municipal bonds(2)	281		1		(9)		273
Other securities(3)	235		2		(10)		227
Total debt securities	577		4		(20)		561
Receivables (payables), net	(23)		—		—		(23)
Total	$	667	$	239	$	(24)	$	882

	December 31, 2023
Short-term investments, primarily cash equivalents	$	21	$	—	$	—	$	21
Equity securities	89		225		(2)		312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	50		2		(1)		51
Municipal bonds	280		3		(8)		275
Other securities	228		3		(11)		220
Total debt securities	558		8		(20)		546
Receivables (payables), net	(7)		—		—		(7)
Total	$	661	$	233	$	(22)	$	872

(1) Maturity dates are 2025-2054.

(2) Maturity dates are 2024-2062.

(3) Maturity dates are 2024-2072.

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Proceeds from sales	$	199	$	138	$	380	$	294
Gross realized gains	10		6		24		8
Gross realized losses	3		3		5		6

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 $497 million at June 30, 2024 and is based on a cost study prepared in 2020, which the CPUC approved in August 2024.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $500 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $60 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $500 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident.

The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed a negligible amount for retrospective premiums based on overall member claims.

The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

SEMPRA - SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2024

Segment Reporting [Abstract]

SEMPRA – SEGMENT INFORMATION

Sempra has three separately managed reportable segments, as follows:

▪Sempra California provides natural gas and electric service to Southern California and part of central California through Sempra’s wholly owned subsidiaries, SDG&E and SoCalGas.

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

▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns a 70% interest in SI Partners.

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


SEGMENT INFORMATION
(Dollars in millions)
	June 30, 2024		December 31, 2023
ASSETS
Sempra California	$	54,462	$	53,430
Sempra Texas Utilities	14,940		14,392
Sempra Infrastructure	21,131		19,430
All other	963		967
Intersegment receivables	(1,023)		(1,038)
Total	$	90,473	$	87,181
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities	$	14,927	$	14,380
Sempra Infrastructure	2,286		2,129
All other	1		1
Total	$	17,214	$	16,510

	Six months ended June 30,
	2024		2023
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
Sempra California	$	2,212	$	2,200
Sempra Infrastructure	1,617		2,078
All other	1		4
Total	$	3,830	$	4,282


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
REVENUES
Sempra California	$	2,625	$	2,700	$	5,766	$	8,115
Sempra Infrastructure	409		660		928		1,856

Adjustments and eliminations	1		(2)		—		(2)
Intersegment revenues(1)	(24)		(23)		(43)		(74)
Total	$	3,011	$	3,335	$	6,651	$	9,895
DEPRECIATION AND AMORTIZATION
Sempra California	$	528	$	476	$	1,049	$	944
Sempra Infrastructure	73		70		145		139
All other	2		3		3		5
Total	$	603	$	549	$	1,197	$	1,088
INTEREST INCOME
Sempra California	$	5	$	5	$	8	$	10
Sempra Infrastructure	7		6		12		21
All other	6		6		11		10
Intercompany eliminations	(1)		—		(1)		—
Total	$	17	$	17	$	30	$	41
INTEREST EXPENSE
Sempra California	$	209	$	194	$	414	$	381
Sempra Infrastructure	—		25		—		120
All other	103		99		203		183
Intercompany eliminations	(1)		(1)		(1)		(1)
Total	$	311	$	317	$	616	$	683
INCOME TAX EXPENSE (BENEFIT)
Sempra California	$	44	$	(17)	$	127	$	84
Sempra Infrastructure	(133)		201		(24)		531
All other	(41)		(9)		(61)		(64)
Total	$	(130)	$	175	$	42	$	551
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	2	$	4	$	3
Sempra Infrastructure	158		151		290		282
	160		153		294		285
Equity earnings, net of income tax:
Sempra Texas Utilities	202		160		385		243
Sempra Infrastructure	71		75		102		79
	273		235		487		322
Total	$	433	$	388	$	781	$	607
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
Sempra California	$	316	$	339	$	898	$	957
Sempra Texas Utilities	202		160		385		243
Sempra Infrastructure	291		208		422		523
All other	(96)		(104)		(191)		(151)
Total	$	713	$	603	$	1,514	$	1,572

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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Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2024

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

June 30, 2024

December 31, 2023

Sempra:

Natural gas

MMBtu

491

361

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

412

268

Notional Amounts of Derivatives Table

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

INTEREST RATE DERIVATIVES

(Dollars in millions)

June 30, 2024

December 31, 2023

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,448

2024-2048

4,451

2024-2048

(1) At June 30, 2024 and December 31, 2023, cash flow hedges accrued interest based on a notional amount of $881 and $488, respectively.

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

FOREIGN CURRENCY DERIVATIVES

(Dollars in millions)

June 30, 2024

December 31, 2023

Notional amount

Maturities

Notional amount

Maturities

Sempra:

Foreign currency derivatives

104

2024-2025

176

2024-2025

Derivative Instruments on the Condensed Consolidated Balance Sheets Table

The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions.


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2024
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	31	$	253	$	—	$	—
Foreign exchange instruments	3		—		—		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	102		29		(103)		(32)
Associated offsetting commodity contracts	(99)		(29)		99		29
Commodity contracts subject to rate recovery	9		11		(50)		(16)
Associated offsetting commodity contracts	(6)		(7)		6		7
Associated offsetting cash collateral	—		—		11		—
Net amounts presented on the balance sheet	40		257		(37)		(12)
Additional cash collateral for commodity contracts not subject to rate recovery	67		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	22		—		—		—
Total(2)	$	129	$	257	$	(37)	$	(12)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	7	$	11	$	(20)	$	(7)
Associated offsetting commodity contracts	(4)		(7)		4		7
Associated offsetting cash collateral	—		—		11		—
Net amounts presented on the balance sheet	3		4		(5)		—
Additional cash collateral for commodity contracts subject to rate recovery	21		—		—		—
Total(2)	$	24	$	4	$	(5)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	2	$	—	$	(30)	$	(9)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	—		—		(28)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	1	$	—	$	(28)	$	(9)

(1) Included in Other Current Assets for SDG&E and SoCalGas.

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


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	17	$	70	$	—	$	—
Foreign exchange instruments	—		—		(9)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	173		52		(170)		(56)
Associated offsetting commodity contracts	(169)		(51)		169		51
Commodity contracts subject to rate recovery	10		8		(228)		(9)
Associated offsetting commodity contracts	(5)		(2)		5		2
Associated offsetting cash collateral	—		—		12		7
Net amounts presented on the balance sheet	26		77		(221)		(5)
Additional cash collateral for commodity contracts not subject to rate recovery	74		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	22		—		—		—
Total(2)	$	122	$	77	$	(221)	$	(5)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	9	$	8	$	(18)	$	(9)
Associated offsetting commodity contracts	(5)		(2)		5		2
Associated offsetting cash collateral	—		—		12		7
Net amounts presented on the balance sheet	4		6		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	21		—		—		—
Total(2)	$	25	$	6	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	1	$	—	$	(210)	$	—
Net amounts presented on the balance sheet	1		—		(210)		—
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	2	$	—	$	(210)	$	—

(1) Included in Other Current Assets for SDG&E and SoCalGas.

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

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

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


HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2024		2023		Location	2024		2023
Sempra:
Cash flow hedges:
Interest rate instruments	$	66	$	94	Interest Expense	$	3	$	—
Interest rate instruments	(3)		41		Equity Earnings(1)	10		14
Foreign exchange instruments	11		(2)		Revenues: Energy- Related Businesses	2		—
					Other Income, Net	1		(1)
Foreign exchange instruments	10		(1)		Equity Earnings(1)	2		(1)
Interest rate and foreign exchange instruments	—		—		Interest Expense	—		1
Fair value hedges:
Foreign exchange instruments	(7)		—		Equity Earnings(1)	—		—
Total	$	77	$	132		$	18	$	13
SoCalGas:
Cash flow hedges:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

	Six months ended June 30,					Six months ended June 30,
	2024		2023		Location	2024		2023
Sempra:
Cash flow hedges:
Interest rate instruments	$	208	$	17	Interest Expense	$	6	$	—
Interest rate instruments	25		24		Equity Earnings(1)	15		21
Foreign exchange instruments	12		(8)		Revenues: Energy- Related Businesses	5		—
					Other Income, Net	1		(2)
Foreign exchange instruments	10		(6)		Equity Earnings(1)	4		(2)
Interest rate and foreign exchange instruments	—		7		Interest Expense	—		1
					Other Income, Net	—		6
Fair value hedges:
Foreign exchange instruments	(7)		—		Equity Earnings(1)	—		—
Total	$	248	$	34		$	31	$	24
SoCalGas:
Cash flow hedges:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

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

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

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


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2024		2023		2024		2023
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	41	$	253	$	120	$	702
Commodity contracts subject to rate recovery	Cost of Natural Gas	(21)		(20)		(27)		(47)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	4		(27)		(19)		(18)
Interest rate instrument	Interest Expense	—		—		—		(47)
Total		$	24	$	206	$	74	$	590
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	4	$	(27)	$	(19)	$	(18)
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(21)	$	(20)	$	(27)	$	(47)

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.

SAN ONOFRE NUCLEAR GENERATING STATION

CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Operating expenses:
Other income, net	$ 30	$ 31	$ 129	$ 72
Interest income	17	17	30	41
Interest expense	(311)	(317)	(616)	(683)
Income before income taxes and equity earnings	308	523	1,013	1,852
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income	871	736	1,752	1,908
Preferred dividends	(11)	(11)	(22)	(22)
Earnings attributable to common shares	713	603	1,514	1,572
SoCalGas
REVENUES
Operating revenues	1,309	1,467	3,114	5,261
Operating expenses:
Cost of natural gas	114	284	579	2,631
Operation and maintenance	707	715	1,320	1,340
Depreciation and amortization	224	208	447	414
Franchise fees and other taxes	60	56	134	145
Total operating expenses	1,105	1,263	2,480	4,530
Operating income	204	204	634	731
Other income, net	13	1	60	(7)
Interest income	2	1	4	5
Interest expense	(78)	(71)	(155)	(140)
Income before income taxes and equity earnings	141	135	543	589
Income tax benefit (expense)	(10)	21	(53)	(73)
Net income	131	156	490	516
Preferred dividends	(1)	(1)	(1)	(1)
Earnings attributable to common shares	$ 130	$ 155	$ 489	$ 515

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2024 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 43
Cash flow hedge gain (loss) to be reclassified, NCI	$ 15
Term of interest rate cash flow hedge (in years)	24 years
SoCalGas
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee
Derivative [Line Items]
Term of interest rate cash flow hedge (in years)	15 years

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR Pinnacle - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Dec. 31, 2023	Nov. 30, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable issued			$ 300
Compound interest rate (as a percent)	5.00%
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Note receivable, net	$ 340	$ 332

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
SoCalGas
Dividends declared per share of preferred stock (in dollars per share)	$ 0.37	$ 0.37	$ 0.75	$ 0.75

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 533	$ 181
Provisions for expected credit losses	94	228
Write-offs	(112)	(43)
Ending balance	515	366
Allowance for credit losses	6		$ 6
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	451		480
Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	52		52
Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	12		1
Other long-term assets \| KKR Pinnacle
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	6		6
Deferred credits and other \| Sempra Infrastructure
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses	5		5
SDG&E
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	144	78
Provisions for expected credit losses	24	63
Write-offs	(42)	(23)
Ending balance	126	118
SDG&E \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	96		116
SDG&E \| Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	26		27
SDG&E \| Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	4		1
SoCalGas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	331	98
Provisions for expected credit losses	45	164
Write-offs	(70)	(20)
Ending balance	306	$ 242
SoCalGas \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	272		306
SoCalGas \| Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	26		25
SoCalGas \| Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	$ 8		$ 0

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Schedule of Equity Method Investments [Line Items]
Interest expense	$ (311)	$ (317)	$ (616)	$ (683)
Income tax benefit (expense)	130	(175)	(42)	(551)
Net income	871	736	1,752	1,908
NCI held by Texas Transmission Investment LLC	(146)	(121)	(215)	(313)
Earnings attributable to common shares	713	603	1,514	1,572
Equity Method Investment, Nonconsolidated Investee or Group of Investees \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,492	1,343	2,950	2,635
Operating expenses	(1,043)	(976)	(2,094)	(2,000)
Income from operations	449	367	856	635
Interest expense	(161)	(133)	(311)	(256)
Income tax benefit (expense)	(55)	(43)	(104)	(67)
Net income	248	197	471	296
NCI held by Texas Transmission Investment LLC	(50)	(40)	(94)	(60)
Earnings attributable to common shares	$ 198	$ 157	$ 377	$ 236

SAN ONOFRE NUCLEAR GENERATING STATION

6 Months Ended

Jun. 30, 2024

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY ASSETS AND LIABILITIES


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023		June 30, 2024		December 31, 2023

Fixed-price contracts and other derivatives	$	49	$	215	$	12	$	14	$	37	$	201
Deferred income taxes recoverable in rates	1,401		1,142		700		626		615		430
Pension and PBOP plan obligations	(226)		(212)		54		48		(280)		(260)
Employee benefit costs	24		24		3		3		21		21
Removal obligations	(3,189)		(3,082)		(2,569)		(2,468)		(620)		(614)
Environmental costs	148		139		115		105		33		34
Sunrise Powerlink fire mitigation	122		124		122		124		—		—
Regulatory balancing accounts(1)(2):
Commodity – electric	(39)		(233)		(39)		(233)		—		—
Commodity – gas, including transportation	(249)		(259)		31		52		(280)		(311)
Safety and reliability	1,153		959		252		207		901		752
Public purpose programs	(424)		(273)		(189)		(144)		(235)		(129)
Wildfire mitigation plan	770		685		770		685		—		—
Liability insurance premium	110		113		83		90		27		23
Other balancing accounts	438		373		(86)		(152)		524		525
Other regulatory (liabilities) assets, net(2)	(106)		(10)		24		49		(128)		(58)
Total	$	(18)	$	(295)	$	(717)	$	(994)	$	615	$	614

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

CPUC GRC

2024 GRC Track 2

2024 GRC Track 3

SDG&E expects to submit in late 2024 an additional request to the CPUC in its 2024 GRC, known as a Track 3 request, for review and recovery of its 2023 wildfire mitigation plan costs.

CPUC COST OF CAPITAL


AUTHORIZED COST OF CAPITAL FOR 2023

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.


AUTHORIZED COST OF CAPITAL FOR 2024 – 2025

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
45.25	%	4.34	%	1.96	%	Long-Term Debt	45.60	%	4.54	%	2.07	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.65		5.54		Common Equity	52.00		10.50		5.46
100.00	%			7.67	%		100.00	%			7.67	%

FERC RATE MATTERS

SAN ONOFRE NUCLEAR GENERATING STATION

NUCLEAR DECOMMISSIONING AND FUNDING

Nuclear Decommissioning Trusts


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2024
Short-term investments, primarily cash equivalents	$	23	$	—	$	—	$	23
Equity securities	90		235		(4)		321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	61		1		(1)		61
Municipal bonds(2)	281		1		(9)		273
Other securities(3)	235		2		(10)		227
Total debt securities	577		4		(20)		561
Receivables (payables), net	(23)		—		—		(23)
Total	$	667	$	239	$	(24)	$	882

	December 31, 2023
Short-term investments, primarily cash equivalents	$	21	$	—	$	—	$	21
Equity securities	89		225		(2)		312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	50		2		(1)		51
Municipal bonds	280		3		(8)		275
Other securities	228		3		(11)		220
Total debt securities	558		8		(20)		546
Receivables (payables), net	(7)		—		—		(7)
Total	$	661	$	233	$	(22)	$	872

(1) Maturity dates are 2025-2054.

(2) Maturity dates are 2024-2062.

(3) Maturity dates are 2024-2072.

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Proceeds from sales	$	199	$	138	$	380	$	294
Gross realized gains	10		6		24		8
Gross realized losses	3		3		5		6

ASSET RETIREMENT OBLIGATION

NUCLEAR INSURANCE

FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2024

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
Sempra:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	20	$	3	$	—			$	23
Equity securities	318		3		—				321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	38		23		—				61
Municipal bonds	—		273		—				273
Other securities	—		227		—				227
Total debt securities	38		523		—				561
Total nuclear decommissioning trusts(2)	376		529		—				905
Short-term investments held in Rabbi Trust	47		—		—				47
Support Agreement, net of related guarantee fees	—		—		23				23
Interest rate instruments	—		284		—		$	—	284
Foreign exchange instruments	—		3		—		—		3
Commodity contracts not subject to rate recovery	—		131		—		(61)		70
Commodity contracts subject to rate recovery	12		2		6		9		29
Total	$	435	$	949	$	29	$	(52)	$	1,361
Liabilities:

Commodity contracts not subject to rate recovery	$	—	$	135	$	—	$	(128)	$	7
Commodity contracts subject to rate recovery	21		45		—		(24)		42
Total	$	21	$	180	$	—	$	(152)	$	49

	Fair value at December 31, 2023
Sempra:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	19	$	2	$	—			$	21
Equity securities	308		4		—				312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	34		17		—				51
Municipal bonds	—		275		—				275
Other securities	—		220		—				220
Total debt securities	34		512		—				546
Total nuclear decommissioning trusts(2)	361		518		—				879
Short-term investments held in Rabbi Trust	67		—		—				67
Support Agreement, net of related guarantee fees	—		—		23				23
Interest rate instruments	—		87		—		$	—	87
Commodity contracts not subject to rate recovery	—		5		—		74		79
Commodity contracts subject to rate recovery	—		1		10		22		33
Total	$	428	$	611	$	33	$	96	$	1,168
Liabilities:
Foreign exchange instruments	$	—	$	9	$	—	$	—	$	9
Commodity contracts not subject to rate recovery	—		6		—		—		6
Commodity contracts subject to rate recovery	20		210		—		(19)		211
Total	$	20	$	225	$	—	$	(19)	$	226

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

(2) Excludes receivables (payables), net.


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
SDG&E:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	20	$	3	$	—			$	23
Equity securities	318		3		—				321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	38		23		—				61
Municipal bonds	—		273		—				273
Other securities	—		227		—				227
Total debt securities	38		523		—				561
Total nuclear decommissioning trusts(2)	376		529		—				905
Commodity contracts subject to rate recovery	12		—		6		$	10	28
Total	$	388	$	529	$	6	$	10	$	933
Liabilities:
Commodity contracts subject to rate recovery	$	21	$	6	$	—	$	(22)	$	5


	Fair value at December 31, 2023
SDG&E:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	19	$	2	$	—			$	21
Equity securities	308		4		—				312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	34		17		—				51
Municipal bonds	—		275		—				275
Other securities	—		220		—				220
Total debt securities	34		512		—				546
Total nuclear decommissioning trusts(2)	361		518		—				879
Commodity contracts subject to rate recovery	—		—		10		$	21	31
Total	$	361	$	518	$	10	$	21	$	910
Liabilities:
Commodity contracts subject to rate recovery	$	20	$	—	$	—	$	(19)	$	1

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

(2) Excludes receivables (payables), net.


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
SoCalGas:
Assets:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	(1)	$	1
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	39	$	—	$	(2)	$	37

	Fair value at December 31, 2023
SoCalGas:
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	210	$	—	$	—	$	210

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

Recurring Fair Value Measures Level 3 Rollforward

The table below sets forth reconciliations of changes in the fair value of CRRs classified as Level 3 in the fair value hierarchy for Sempra and SDG&E.


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended June 30,
	2024		2023
Balance at April 1	$	9	$	30
Realized and unrealized gains (losses), net	(2)		(4)
Allocated transmission instruments	—		(2)
Settlements	(1)		(4)
Balance at June 30	$	6	$	20
Change in unrealized losses relating to instruments still held at June 30	$	(1)	$	(7)

	Six months ended June 30,
	2024		2023
Balance at January 1	$	10	$	35
Realized and unrealized gains (losses), net	(3)		(8)
Allocated transmission instruments	—		(2)
Settlements	(1)		(5)
Balance at June 30	$	6	$	20
Change in unrealized losses relating to instruments still held at June 30	$	(2)	$	(9)

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

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


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2024		2023
Balance at April 1	$	23	$	24
Realized and unrealized gains (losses), net(1)	2		1
Settlements	(2)		(2)
Balance at June 30(2)	$	23	$	23
Change in unrealized gains relating to instruments still held at June 30	$	2	$	1

	Six months ended June 30,
	2024		2023
Balance at January 1	$	23	$	17
Realized and unrealized gains (losses), net(1)	4		10
Settlements	(4)		(4)
Balance at June 30(2)	$	23	$	23
Change in unrealized gains relating to instruments still held at June 30	$	3	$	9

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

(2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2024 on Sempra’s Condensed Consolidated Balance Sheet.

Schedule of Fair Value Inputs

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


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

Settlement year	Price per MWh					Median price per MWh
2024	$	(3.69)	to	$	9.55	$	(0.44)
2023	(3.09)		to	10.71		(0.56)

Fair Value of Financial Instruments

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


FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2024
Sempra:

Long-term note receivable(1)	$	342	$	—	$	—	$	326	$	326
Long-term amounts due to unconsolidated affiliates	302		—		271		—		271
Total long-term debt(2)	29,704		—		26,850		—		26,850
SDG&E:
Total long-term debt(3)	$	8,950	$	—	$	7,747	$	—	$	7,747
SoCalGas:
Total long-term debt(4)	$	7,259	$	—	$	6,715	$	—	$	6,715

	December 31, 2023
Sempra:
Long-term note receivable(1)	$	334	$	—	$	—	$	318	$	318
Long-term amounts due to unconsolidated affiliates	312		—		283		—		283
Total long-term debt(2)	27,716		—		25,617		—		25,617
SDG&E:
Total long-term debt(3)	$	8,750	$	—	$	7,856	$	—	$	7,856
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	6,442	$	—	$	6,442

(1) Before allowances for credit losses of $6 at both June 30, 2024 and December 31, 2023. Excludes unamortized transaction costs of $4 at both June 30, 2024 and December 31, 2023.

(2) After the effects of interest rate swaps. Before reductions of unamortized discount and debt issuance costs of $346 and $322 at June 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,319 and $1,340 at June 30, 2024 and December 31, 2023, respectively.

(3) Before reductions of unamortized discount and debt issuance costs of $98 and $89 at June 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $1,213 and $1,233 at June 30, 2024 and December 31, 2023, respectively.

(4) Before reductions of unamortized discount and debt issuance costs of $61 and $55 at June 30, 2024 and December 31, 2023, respectively, and excluding finance lease obligations of $106 and $107 at June 30, 2024 and December 31, 2023, respectively.

Tabular disclosure of the fair value measurement of assets using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets) and gains or losses recognized in other comprehensive income (loss), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issues, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs), by class of asset.

SEMPRA - SEGMENT INFORMATION - NARRATIVE (Details)	6 Months Ended
SEMPRA - SEGMENT INFORMATION - NARRATIVE (Details)	Jun. 30, 2024 segment
Segment Reporting Information [Line Items]
Number of reportable segments	3
Sempra Infrastructure \| SI Partners
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	70.00%
Oncor Electric Delivery Company LLC Additional Acquisition \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	80.25%
Sharyland Holdings, LP \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	50.00%

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Interest income	$ 2	$ 1	$ 3	$ 3
Total revenues from sales-type leases	2	1	3	3
Fixed lease payments	87	76	176	156
Variable lease payments	10	14	20	16
Total revenues from operating leases	97	90	196	172
Depreciation expense	$ 18	$ 15	$ 36	$ 30

FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2024

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 tables below set forth our financial assets and liabilities, by level within the fair value hierarchy, that were accounted for at fair value on a recurring basis at June 30, 2024 and December 31, 2023. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair-valued assets and liabilities and their placement within the fair value hierarchy. We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2023.

The 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 at SDG&E, as we discuss below in “Level 3 Information – SDG&E.”

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

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


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
Sempra:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	20	$	3	$	—			$	23
Equity securities	318		3		—				321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	38		23		—				61
Municipal bonds	—		273		—				273
Other securities	—		227		—				227
Total debt securities	38		523		—				561
Total nuclear decommissioning trusts(2)	376		529		—				905
Short-term investments held in Rabbi Trust	47		—		—				47
Support Agreement, net of related guarantee fees	—		—		23				23
Interest rate instruments	—		284		—		$	—	284
Foreign exchange instruments	—		3		—		—		3
Commodity contracts not subject to rate recovery	—		131		—		(61)		70
Commodity contracts subject to rate recovery	12		2		6		9		29
Total	$	435	$	949	$	29	$	(52)	$	1,361
Liabilities:

Commodity contracts not subject to rate recovery	$	—	$	135	$	—	$	(128)	$	7
Commodity contracts subject to rate recovery	21		45		—		(24)		42
Total	$	21	$	180	$	—	$	(152)	$	49

	Fair value at December 31, 2023
Sempra:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	19	$	2	$	—			$	21
Equity securities	308		4		—				312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	34		17		—				51
Municipal bonds	—		275		—				275
Other securities	—		220		—				220
Total debt securities	34		512		—				546
Total nuclear decommissioning trusts(2)	361		518		—				879
Short-term investments held in Rabbi Trust	67		—		—				67
Support Agreement, net of related guarantee fees	—		—		23				23
Interest rate instruments	—		87		—		$	—	87
Commodity contracts not subject to rate recovery	—		5		—		74		79
Commodity contracts subject to rate recovery	—		1		10		22		33
Total	$	428	$	611	$	33	$	96	$	1,168
Liabilities:
Foreign exchange instruments	$	—	$	9	$	—	$	—	$	9
Commodity contracts not subject to rate recovery	—		6		—		—		6
Commodity contracts subject to rate recovery	20		210		—		(19)		211
Total	$	20	$	225	$	—	$	(19)	$	226

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

(2) Excludes receivables (payables), net.


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
SDG&E:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	20	$	3	$	—			$	23
Equity securities	318		3		—				321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	38		23		—				61
Municipal bonds	—		273		—				273
Other securities	—		227		—				227
Total debt securities	38		523		—				561
Total nuclear decommissioning trusts(2)	376		529		—				905
Commodity contracts subject to rate recovery	12		—		6		$	10	28
Total	$	388	$	529	$	6	$	10	$	933
Liabilities:
Commodity contracts subject to rate recovery	$	21	$	6	$	—	$	(22)	$	5


	Fair value at December 31, 2023
SDG&E:
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	19	$	2	$	—			$	21
Equity securities	308		4		—				312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	34		17		—				51
Municipal bonds	—		275		—				275
Other securities	—		220		—				220
Total debt securities	34		512		—				546
Total nuclear decommissioning trusts(2)	361		518		—				879
Commodity contracts subject to rate recovery	—		—		10		$	21	31
Total	$	361	$	518	$	10	$	21	$	910
Liabilities:
Commodity contracts subject to rate recovery	$	20	$	—	$	—	$	(19)	$	1

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

(2) Excludes receivables (payables), net.


RECURRING FAIR VALUE MEASURES
(Dollars in millions)
	Level 1		Level 2		Level 3		Netting(1)		Total
	Fair value at June 30, 2024
SoCalGas:
Assets:
Commodity contracts subject to rate recovery	$	—	$	2	$	—	$	(1)	$	1
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	39	$	—	$	(2)	$	37

	Fair value at December 31, 2023
SoCalGas:
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	210	$	—	$	—	$	210

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

Level 3 Information

SDG&E

The table below sets forth reconciliations of changes in the fair value of CRRs classified as Level 3 in the fair value hierarchy for Sempra and SDG&E.


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended June 30,
	2024		2023
Balance at April 1	$	9	$	30
Realized and unrealized gains (losses), net	(2)		(4)
Allocated transmission instruments	—		(2)
Settlements	(1)		(4)
Balance at June 30	$	6	$	20
Change in unrealized losses relating to instruments still held at June 30	$	(1)	$	(7)

	Six months ended June 30,
	2024		2023
Balance at January 1	$	10	$	35
Realized and unrealized gains (losses), net	(3)		(8)
Allocated transmission instruments	—		(2)
Settlements	(1)		(5)
Balance at June 30	$	6	$	20
Change in unrealized losses relating to instruments still held at June 30	$	(2)	$	(9)

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

Inputs used to determine the fair value of CRRs are reviewed and compared with market conditions to determine reasonableness.

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


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

Settlement year	Price per MWh					Median price per MWh
2024	$	(3.69)	to	$	9.55	$	(0.44)
2023	(3.09)		to	10.71		(0.56)

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

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

Other Sempra

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


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2024		2023
Balance at April 1	$	23	$	24
Realized and unrealized gains (losses), net(1)	2		1
Settlements	(2)		(2)
Balance at June 30(2)	$	23	$	23
Change in unrealized gains relating to instruments still held at June 30	$	2	$	1

	Six months ended June 30,
	2024		2023
Balance at January 1	$	23	$	17
Realized and unrealized gains (losses), net(1)	4		10
Settlements	(4)		(4)
Balance at June 30(2)	$	23	$	23
Change in unrealized gains relating to instruments still held at June 30	$	3	$	9

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

(2) Includes $7 in Other Current Assets and $16 in Other Long-term Assets at June 30, 2024 on Sempra’s Condensed Consolidated Balance Sheet.

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

Fair Value of Financial Instruments

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


FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2024
Sempra:

Long-term note receivable(1)	$	342	$	—	$	—	$	326	$	326
Long-term amounts due to unconsolidated affiliates	302		—		271		—		271
Total long-term debt(2)	29,704		—		26,850		—		26,850
SDG&E:
Total long-term debt(3)	$	8,950	$	—	$	7,747	$	—	$	7,747
SoCalGas:
Total long-term debt(4)	$	7,259	$	—	$	6,715	$	—	$	6,715

	December 31, 2023
Sempra:
Long-term note receivable(1)	$	334	$	—	$	—	$	318	$	318
Long-term amounts due to unconsolidated affiliates	312		—		283		—		283
Total long-term debt(2)	27,716		—		25,617		—		25,617
SDG&E:
Total long-term debt(3)	$	8,750	$	—	$	7,856	$	—	$	7,856
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	6,442	$	—	$	6,442

(1) Before allowances for credit losses of $6 at both June 30, 2024 and December 31, 2023. Excludes unamortized transaction costs of $4 at both June 30, 2024 and December 31, 2023.

We provide the fair values for the securities held in the NDT related to SONGS in Note 10.

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.

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Dividends declared per share of common stock (in dollars per share)	$ 0.62	$ 0.59	$ 1.24	$ 1.19
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19	$ 24.38	$ 24.38

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Pay vs Performance Disclosure
Net income attributable to Sempra	$ 725	$ 615	$ 1,537	$ 1,595

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Jun. 30, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	6.07%	5.96%
SoCalGas
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	6.02%	5.44%

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

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

Jun. 30, 2024

Dec. 31, 2023

$ 228

$ 236

^[1]

1,552

2,151

^[1]

441

561

^[1]

^[1]

467

482

^[1]

226

^[1]

1,176

1,189

^[1]

^[1]

4,378

5,470

^[1]

4,011

3,771

^[1]

769

301

^[1]

711

723

^[1]

1,857

1,603

^[1]

28,411

26,751

^[1]

75,923

72,495

^[1]

(18,239)

(17,535)

^[1]

57,684

54,960

^[1]

90,473

87,181

^[1]

Short-term debt

2,197

2,342

^[1]

Accounts payable – trade

1,753

2,211

^[1]

Accounts payable – other

257

224

^[1]

378

526

^[1]

Current portion of long-term debt and finance leases

125

553

^[1]

1,711

975

^[1]

1,176

1,189

^[1]

9,540

10,090

^[1]

28,966

27,759

^[1]

3,959

3,739

^[1]

Pension obligation, net of plan assets

334

^[1]

405

407

^[1]

5,486

5,254

^[1]

3,689

3,642

^[1]

2,373

2,329

^[1]

16,548

15,678

^[1]

^[1]

Equity:

12,250

12,204

^[1]

16,461

15,732

^[1]

(121)

(150)

^[1]

29,479

28,675

^[1]

90,473

87,181

^[1]

Related Party

^[1]

Nonrelated Party

1,202

1,374

^[1]

^[1]

583

985

^[1]

102

^[1]

^[1]

260

277

^[1]

204

^[1]

936

950

^[1]

100

^[1]

1,956

2,642

^[1]

1,910

1,715

^[1]

407

^[1]

^[1]

693

645

^[1]

3,033

2,451

^[1]

27,867

27,025

^[1]

(8,122)

(7,852)

^[1]

19,745

19,173

^[1]

24,734

24,266

^[1]

Short-term debt

406

946

^[1]

Accounts payable – trade

464

811

^[1]

Accounts payable – other

203

184

^[1]

179

213

^[1]

Current portion of long-term debt and finance leases

103

^[1]

873

523

^[1]

936

950

^[1]

^[1]

3,590

4,407

^[1]

6,431

6,288

^[1]

1,295

1,202

^[1]

Pension obligation, net of plan assets

269

^[1]

221

231

^[1]

1,828

1,586

^[1]

2,823

2,774

^[1]

376

368

^[1]

6,812

6,161

^[1]

^[1]

Equity:

Preferred stock

^[1]

2,316

^[1]

5,584

5,095

^[1]

(21)

(23)

^[1]

7,901

7,410

^[1]

24,734

24,266

^[1]

SoCalGas | Related Party

SoCalGas | Nonrelated Party

^[1]

$ 381

$ 566

^[1]

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (130)	$ 175	$ 42	$ 551
Income before income taxes and equity earnings	308	523	1,013	1,852
Equity earnings, before income tax:	160	153	294	285
Pretax income	$ 468	$ 676	$ 1,307	$ 2,137
Effective income tax rate (as a percent)	(28.00%)	26.00%	3.00%	26.00%
SDG&E
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 34	$ 4	$ 74	$ 11
Income before income taxes and equity earnings	$ 220	$ 188	$ 483	$ 453
Effective income tax rate (as a percent)	15.00%	2.00%	15.00%	2.00%
SoCalGas
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 10	$ (21)	$ 53	$ 73
Income before income taxes and equity earnings	$ 141	$ 135	$ 543	$ 589
Effective income tax rate (as a percent)	7.00%	(16.00%)	10.00%	12.00%

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.

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

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

Condensed Financial Statements

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	$ 905	$ 879
Short-term investments held in Rabbi Trust	47	67
Support Agreement, net of related guarantee fees	23	23
Netting adjustment	(52)	96
Total	1,361	1,168
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(152)	(19)
Total	49	226
Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	23	21
Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	321	312
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	61	51
Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	273	275
Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	227	220
Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	561	546
Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0	0
Derivative assets, Total	284	87
Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	(61)	74
Derivative assets, Total	70	79
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(128)	0
Derivative liabilities	7	6
Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	9	22
Derivative assets, Total	29	33
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(24)	(19)
Derivative liabilities	42	211
Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	0
Derivative assets, Total	3
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment		0
Derivative liabilities		9
Level 1
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	376	361
Short-term investments held in Rabbi Trust	47	67
Support Agreement, net of related guarantee fees	0	0
Total	435	428
Liabilities, Fair Value Disclosure [Abstract]
Total	21	20
Level 1 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	20	19
Level 1 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	318	308
Level 1 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	38	34
Level 1 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 1 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 1 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	38	34
Level 1 \| Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Level 1 \| Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 1 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	12	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	21	20
Level 1 \| Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting		0
Level 2
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	529	518
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	949	611
Liabilities, Fair Value Disclosure [Abstract]
Total	180	225
Level 2 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	2
Level 2 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	4
Level 2 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	23	17
Level 2 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	273	275
Level 2 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	227	220
Level 2 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	523	512
Level 2 \| Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	284	87
Level 2 \| Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	131	5
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	135	6
Level 2 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	2	1
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	45	210
Level 2 \| Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	3
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting		9
Level 3
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	23	23
Total	29	33
Liabilities, Fair Value Disclosure [Abstract]
Total	0	0
Level 3 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Level 3 \| Interest rate instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Level 3 \| Commodity contracts not subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 3 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	10
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
Level 3 \| Foreign exchange instruments
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting		0
SDG&E
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	905	879
Netting adjustment	10	21
Total	933	910
SDG&E \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	23	21
SDG&E \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	321	312
SDG&E \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	61	51
SDG&E \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	273	275
SDG&E \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	227	220
SDG&E \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	561	546
SDG&E \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	10	21
Derivative assets, Total	28	31
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(22)	(19)
Derivative liabilities	5	1
SDG&E \| Level 1
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	376	361
Total	388	361
SDG&E \| Level 1 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	20	19
SDG&E \| Level 1 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	318	308
SDG&E \| Level 1 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	38	34
SDG&E \| Level 1 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 1 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 1 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	38	34
SDG&E \| Level 1 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	12	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	21	20
SDG&E \| Level 2
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	529	518
Total	529	518
SDG&E \| Level 2 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	2
SDG&E \| Level 2 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	3	4
SDG&E \| Level 2 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	23	17
SDG&E \| Level 2 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	273	275
SDG&E \| Level 2 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	227	220
SDG&E \| Level 2 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	523	512
SDG&E \| Level 2 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	6	0
SDG&E \| Level 3
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
Total	6	10
SDG&E \| Level 3 \| Short-term investments, primarily cash equivalents
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Equity securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Municipal bonds
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Other securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Total debt securities
Assets, Fair Value Disclosure [Abstract]
Total nuclear decommissioning trusts	0	0
SDG&E \| Level 3 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	6	10
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SoCalGas \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Netting adjustment	(1)	1
Derivative assets, Total	1	2
Liabilities, Fair Value Disclosure [Abstract]
Netting adjustment	(2)	0
Derivative liabilities	37	210
SoCalGas \| Level 1 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	0	0
SoCalGas \| Level 2 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	2	1
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	39	210
SoCalGas \| Level 3 \| Commodity contracts subject to rate recovery
Assets, Fair Value Disclosure [Abstract]
Derivative asset, before netting	0	0
Liabilities, Fair Value Disclosure [Abstract]
Derivative liability, before netting	$ 0	$ 0

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	$ 155	$ 110	$ 300	$ 183
SDG&E
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	27	31	53	62
SoCalGas
Capitalized Financing Costs Disclosure [Line Items]
Capitalized financing costs	$ 26	$ 20	$ 50	$ 35

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	6 Months Ended
	Jun. 30, 2024 segment
Segment Reporting Information [Line Items]
Number of reportable segments	3
SDG&E
Segment Reporting Information [Line Items]
Number of reportable segments	1
SoCalGas
Segment Reporting Information [Line Items]
Number of reportable segments	1
Sempra California
Segment Reporting Information [Line Items]
Number of reportable segments	1

SEMPRA - INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)

6 Months Ended

Jun. 30, 2024

Investments [Abstract]

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


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Operating revenues	$	1,492	$	1,343	$	2,950	$	2,635
Operating expenses	(1,043)		(976)		(2,094)		(2,000)
Income from operations	449		367		856		635
Interest expense	(161)		(133)		(311)		(256)
Income tax expense	(55)		(43)		(104)		(67)
Net income	248		197		471		296
NCI held by Texas Transmission Investment LLC	(50)		(40)		(94)		(60)
Earnings attributable to Sempra(1)	198		157		377		236

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details) $ in Millions	Jun. 30, 2024 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 9,900
Available unused credit	7,958
Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(64)
Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(852)
Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(1,026)
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity	4,000
Available unused credit	3,254
Sempra \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Sempra \| Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(746)
Sempra \| Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SDG&E
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Available unused credit	1,500
SDG&E \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SDG&E \| Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SDG&E \| Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SoCalGas
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,200
Available unused credit	1,094
SoCalGas \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SoCalGas \| Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(106)
SoCalGas \| Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Maximum borrowing capacity	500
Available unused credit	150
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due September 2025 \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,000
Available unused credit	975
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2026 \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Maximum borrowing capacity	1,500
Available unused credit	849
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2028 \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| Commercial paper outstanding \| IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| Commercial paper outstanding \| IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| Commercial paper outstanding \| IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Line of credit outstanding	0
SI Partners and IEnova \| Amounts outstanding \| IEnova and SI Partners Committed Line Of Credit Due September 2025
Line of Credit Facility [Line Items]
Line of credit outstanding	(350)
SI Partners and IEnova \| Amounts outstanding \| IEnova and SI Partners Committed Line Of Credit Due August 2026
Line of Credit Facility [Line Items]
Line of credit outstanding	(25)
SI Partners and IEnova \| Amounts outstanding \| IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Line of credit outstanding	(651)
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity	200
Available unused credit	136
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Committed Letters of Credit Outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding	(64)
Port Arthur LNG \| Commercial paper outstanding \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Port Arthur LNG \| Amounts outstanding \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Line of credit outstanding	$ 0

DERIVATIVE FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2024

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

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

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

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

HEDGE ACCOUNTING

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

ENERGY DERIVATIVES

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

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

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

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

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

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

June 30, 2024

December 31, 2023

Sempra:

Natural gas

MMBtu

491

361

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

412

268

INTEREST RATE DERIVATIVES

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

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

INTEREST RATE DERIVATIVES

(Dollars in millions)

June 30, 2024

December 31, 2023

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,448

2024-2048

4,451

2024-2048

(1) At June 30, 2024 and December 31, 2023, cash flow hedges accrued interest based on a notional amount of $881 and $488, respectively.

FOREIGN CURRENCY DERIVATIVES

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

In May 2024, Oncor entered into cross-currency swaps designated as fair value hedges intended to offset foreign currency exchange rate risk related to its Euro-denominated debt.

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

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

FOREIGN CURRENCY DERIVATIVES

(Dollars in millions)

June 30, 2024

December 31, 2023

Notional amount

Maturities

Notional amount

Maturities

Sempra:

Foreign currency derivatives

104

2024-2025

176

2024-2025

FINANCIAL STATEMENT PRESENTATION

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


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2024
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	31	$	253	$	—	$	—
Foreign exchange instruments	3		—		—		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	102		29		(103)		(32)
Associated offsetting commodity contracts	(99)		(29)		99		29
Commodity contracts subject to rate recovery	9		11		(50)		(16)
Associated offsetting commodity contracts	(6)		(7)		6		7
Associated offsetting cash collateral	—		—		11		—
Net amounts presented on the balance sheet	40		257		(37)		(12)
Additional cash collateral for commodity contracts not subject to rate recovery	67		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	22		—		—		—
Total(2)	$	129	$	257	$	(37)	$	(12)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	7	$	11	$	(20)	$	(7)
Associated offsetting commodity contracts	(4)		(7)		4		7
Associated offsetting cash collateral	—		—		11		—
Net amounts presented on the balance sheet	3		4		(5)		—
Additional cash collateral for commodity contracts subject to rate recovery	21		—		—		—
Total(2)	$	24	$	4	$	(5)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	2	$	—	$	(30)	$	(9)
Associated offsetting commodity contracts	(2)		—		2		—
Net amounts presented on the balance sheet	—		—		(28)		(9)
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	1	$	—	$	(28)	$	(9)

(1) Included in Other Current Assets for SDG&E and SoCalGas.

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


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	17	$	70	$	—	$	—
Foreign exchange instruments	—		—		(9)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	173		52		(170)		(56)
Associated offsetting commodity contracts	(169)		(51)		169		51
Commodity contracts subject to rate recovery	10		8		(228)		(9)
Associated offsetting commodity contracts	(5)		(2)		5		2
Associated offsetting cash collateral	—		—		12		7
Net amounts presented on the balance sheet	26		77		(221)		(5)
Additional cash collateral for commodity contracts not subject to rate recovery	74		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	22		—		—		—
Total(2)	$	122	$	77	$	(221)	$	(5)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	9	$	8	$	(18)	$	(9)
Associated offsetting commodity contracts	(5)		(2)		5		2
Associated offsetting cash collateral	—		—		12		7
Net amounts presented on the balance sheet	4		6		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	21		—		—		—
Total(2)	$	25	$	6	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	1	$	—	$	(210)	$	—
Net amounts presented on the balance sheet	1		—		(210)		—
Additional cash collateral for commodity contracts subject to rate recovery	1		—		—		—
Total	$	2	$	—	$	(210)	$	—

(1) Included in Other Current Assets for SDG&E and SoCalGas.

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

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


HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2024		2023		Location	2024		2023
Sempra:
Cash flow hedges:
Interest rate instruments	$	66	$	94	Interest Expense	$	3	$	—
Interest rate instruments	(3)		41		Equity Earnings(1)	10		14
Foreign exchange instruments	11		(2)		Revenues: Energy- Related Businesses	2		—
					Other Income, Net	1		(1)
Foreign exchange instruments	10		(1)		Equity Earnings(1)	2		(1)
Interest rate and foreign exchange instruments	—		—		Interest Expense	—		1
Fair value hedges:
Foreign exchange instruments	(7)		—		Equity Earnings(1)	—		—
Total	$	77	$	132		$	18	$	13
SoCalGas:
Cash flow hedges:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

	Six months ended June 30,					Six months ended June 30,
	2024		2023		Location	2024		2023
Sempra:
Cash flow hedges:
Interest rate instruments	$	208	$	17	Interest Expense	$	6	$	—
Interest rate instruments	25		24		Equity Earnings(1)	15		21
Foreign exchange instruments	12		(8)		Revenues: Energy- Related Businesses	5		—
					Other Income, Net	1		(2)
Foreign exchange instruments	10		(6)		Equity Earnings(1)	4		(2)
Interest rate and foreign exchange instruments	—		7		Interest Expense	—		1
					Other Income, Net	—		6
Fair value hedges:
Foreign exchange instruments	(7)		—		Equity Earnings(1)	—		—
Total	$	248	$	34		$	31	$	24
SoCalGas:
Cash flow hedges:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

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

For Sempra, we expect that net gains before NCI of $43 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $15 million attributable to NCI) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at June 30, 2024 is approximately 24 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 15 years.

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


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2024		2023		2024		2023
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	41	$	253	$	120	$	702
Commodity contracts subject to rate recovery	Cost of Natural Gas	(21)		(20)		(27)		(47)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	4		(27)		(19)		(18)
Interest rate instrument	Interest Expense	—		—		—		(47)
Total		$	24	$	206	$	74	$	590
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	4	$	(27)	$	(19)	$	(18)
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(21)	$	(20)	$	(27)	$	(47)

CREDIT RISK RELATED CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at June 30, 2024 and December 31, 2023 was $44 million and $215 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at June 30, 2024 and December 31, 2023 was $37 million and $210 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at June 30, 2024 or December 31, 2023. At June 30, 2024, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $44 million and $37 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.

DEBT AND CREDIT FACILITIES - UNCOMMITTED LETTERS OF CREDIT (Details) - Uncommitted Letters of Credit Outstanding $ in Millions	Jun. 30, 2024 USD ($)
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount	$ 499
SDG&E
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount	26
SoCalGas
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount	20
Other Sempra
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount	$ 453

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

Jun. 30, 2024

Dec. 31, 2023

$ 228

$ 236

^[1]

Restricted cash

^[1]

1,552

2,151

^[1]

441

561

^[1]

^[1]

Income taxes receivable

^[1]

467

482

^[1]

Prepaid expenses

173

273

^[1]

Fixed-price contracts and other derivatives

226

^[1]

129

122

^[1]

1,176

1,189

^[1]

^[1]

4,378

5,470

^[1]

Restricted cash

107

104

^[1]

4,011

3,771

^[1]

Nuclear decommissioning trusts

769

301

^[1]

882

872

^[1]

Dedicated assets in support of certain benefit plans

547

549

^[1]

134

129

^[1]

Investment in Oncor Holdings

711

723

^[1]

14,809

14,266

^[1]

Other investments

2,405

2,244

^[1]

Goodwill

1,602

^[1]

Other intangible assets

305

318

^[1]

Wildfire fund

272

269

^[1]

1,857

1,603

^[1]

28,411

26,751

^[1]

75,923

72,495

^[1]

(18,239)

(17,535)

^[1]

57,684

54,960

^[1]

90,473

87,181

^[1]

Dividends and interest payable

Short-term debt

2,197

2,342

^[1]

Accounts payable – trade

1,753

2,211

^[1]

Accounts payable – other

257

224

^[1]

738

691

^[1]

378

526

^[1]

Current portion of long-term debt and finance leases

125

553

^[1]

1,711

975

^[1]

1,176

1,189

^[1]

9,540

10,090

^[1]

28,966

27,759

^[1]

Due to unconsolidated affiliates

302

307

^[1]

3,959

3,739

^[1]

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

334

^[1]

405

407

^[1]

5,486

5,254

^[1]

3,689

3,642

^[1]

2,373

2,329

^[1]

16,548

15,678

^[1]

^[1]

Equity:

12,250

12,204

^[1]

16,461

15,732

^[1]

(121)

(150)

^[1]

Preferred stock of subsidiary

29,479

28,675

^[1]

^[1]

Other noncontrolling interests

5,920

4,959

^[1]

Total equity

35,419

33,654

^[1]

90,473

87,181

^[1]

Related Party

^[1]

Due to unconsolidated affiliates

302

307

Nonrelated Party

Public Utilities, General Disclosures [Abstract]

1,202

1,374

^[1]

Series C Preferred Stock

Equity:

Preferred stock

$ 889

^[1]

[1]	Derived from audited financial statements.

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

6 Months Ended

Jun. 30, 2024

Schedule of Nuclear Decommissioning Trusts Investments

Nuclear Decommissioning Trusts


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2024
Short-term investments, primarily cash equivalents	$	23	$	—	$	—	$	23
Equity securities	90		235		(4)		321
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	61		1		(1)		61
Municipal bonds(2)	281		1		(9)		273
Other securities(3)	235		2		(10)		227
Total debt securities	577		4		(20)		561
Receivables (payables), net	(23)		—		—		(23)
Total	$	667	$	239	$	(24)	$	882

	December 31, 2023
Short-term investments, primarily cash equivalents	$	21	$	—	$	—	$	21
Equity securities	89		225		(2)		312
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	50		2		(1)		51
Municipal bonds	280		3		(8)		275
Other securities	228		3		(11)		220
Total debt securities	558		8		(20)		546
Receivables (payables), net	(7)		—		—		(7)
Total	$	661	$	233	$	(22)	$	872

(1) Maturity dates are 2025-2054.

(2) Maturity dates are 2024-2062.

(3) Maturity dates are 2024-2072.

Schedule of Sales of Securities By Nuclear Decommissioning Trusts

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2024		2023		2024		2023
Proceeds from sales	$	199	$	138	$	380	$	294
Gross realized gains	10		6		24		8
Gross realized losses	3		3		5		6

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

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

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

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

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

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

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

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

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

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

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

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

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME (EXPENSE), NET (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Other Income [Line Items]
Allowance for equity funds used during construction	$ 38	$ 37	$ 75	$ 70
Investment gains, net	3	5	19	17
Gains (losses) on interest rate and foreign exchange instruments, net	1	(1)	1	4
Foreign currency transaction (losses) gains, net	(2)	3	(1)	4
Non-service components of net periodic benefit cost	32	26	4	51
Interest on regulatory balancing accounts, net	24	19	42	37
Sundry, net	(2)	(6)	(3)	(9)
Total	30	31	129	72
SDG&E
Other Income [Line Items]
Allowance for equity funds used during construction	19	23	39	46
Non-service components of net periodic benefit cost	3	5	(7)	9
Interest on regulatory balancing accounts, net	11	11	18	21
Sundry, net	(4)	(7)	(8)	(8)
Total	23	22	56	50
SoCalGas
Other Income [Line Items]
Allowance for equity funds used during construction	19	14	36	24
Non-service components of net periodic benefit cost	17	19	(4)	38
Interest on regulatory balancing accounts, net	13	8	24	16
Sundry, net	(2)	(2)	(4)	(9)
Total	$ 13	$ 1	$ 60	$ (7)

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Related Party Transaction [Line Items]
Revenues	$ 3,011	$ 3,335	$ 6,651	$ 9,895
Interest expense	311	317	616	683
Related Party
Related Party Transaction [Line Items]
Revenues	10	11	20	24
Interest expense	3	4	7	8
SDG&E
Related Party Transaction [Line Items]
Revenues	1,355	1,262	2,734	2,915
Interest expense	131	123	259	241
Operating revenues	1,355	1,262	2,734	2,915
SDG&E \| Related Party
Related Party Transaction [Line Items]
Operating revenues	5	6	11	10
Cost of sales	35	27	75	57
SoCalGas
Related Party Transaction [Line Items]
Revenues	1,309	1,467	3,114	5,261
Interest expense	78	71	155	140
Operating revenues	1,309	1,467	3,114	5,261
SoCalGas \| Related Party
Related Party Transaction [Line Items]
Operating revenues	37	28	81	62
Cost of sales	$ 0	$ 4	$ (3)	$ 35

Amount of interest expense classified as operating and nonoperating. Includes, but is not limited to, cost of borrowing accounted for as interest expense.

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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

Jun. 30, 2024

Dec. 31, 2023

Jun. 30, 2023

Dec. 31, 2022