0001032208-23-000057 | 10-Q | XBRL Viewer

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CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income	$ 854	$ 561	$ 2,762	$ 1,877
Comprehensive income			3,094	2,121
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive (loss) income	309	67	333	245
Pretax amount
Net income	680	517	2,826	2,125
Comprehensive income			2,991	2,371
Pension and other postretirement benefits	2	2	(8)	15
Total other comprehensive (loss) income	147	62	166	247
Income tax benefit (expense)
Net income	52	(21)	(499)	(435)
Comprehensive income			(544)	(493)
Pension and other postretirement benefits	(1)	0	(2)	(2)
Total other comprehensive (loss) income	(40)	(15)	(45)	(58)
Net-of-tax amount
Net income	732	496	2,327	1,690
Comprehensive income			2,447	1,878
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive (loss) income	107	47	121	189
San Diego Gas and Electric Company
Net income	274	271	716	681
Total other comprehensive (loss) income		1		1
San Diego Gas and Electric Company \| Pretax amount
Net income	259	306	712	822
Comprehensive income	259	307	712	823
Pension and other postretirement benefits		1		1
Total other comprehensive (loss) income		1		1
San Diego Gas and Electric Company \| Income tax benefit (expense)
Net income	15	(35)	4	(141)
Comprehensive income	15	(35)	4	(141)
Pension and other postretirement benefits		0		0
Total other comprehensive (loss) income		0		0
San Diego Gas and Electric Company \| Net-of-tax amount
Net income	274	271	716	681
Comprehensive income	$ 274	272	$ 716	682
Pension and other postretirement benefits		1		1
Total other comprehensive (loss) income		$ 1		$ 1

- Definition

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

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- Definition

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

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+ Details

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS NARRATIVE (Details) $ / shares in Units, $ in Millions					1 Months Ended		3 Months Ended		9 Months Ended
	Aug. 02, 2023 shares	Mar. 20, 2023 USD ($)	Apr. 06, 2022 USD ($) $ / shares shares	Jan. 11, 2022 USD ($) $ / shares shares	Sep. 30, 2023 USD ($) shares	Jun. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) shares	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) shares	Sep. 30, 2022 USD ($) shares	May 12, 2023 shares	May 11, 2023 shares	Dec. 31, 2022 shares	Dec. 21, 2021 USD ($)	Oct. 01, 2021 USD ($)
Noncontrolling Interest [Line Items]
Common stock, shares authorized (in shares) \| shares	1,125,000,000				1,125,000,000		1,125,000,000		1,125,000,000		1,125,000,000	750,000,000	1,125,000,000
Stock split, conversion ratio	2
Stock dividend (in percent)	100.00%
Increase in equity							$ 496	$ 2	$ 1,091	$ 15
Increase in shareholders' equity							986	$ 1	1,241	$ 1,419
Port Arthur LNG
Noncontrolling Interest [Line Items]
Increase in equity		$ 234
SI Partners
Noncontrolling Interest [Line Items]
Increase in shareholders' equity							200
Sale of noncontrolling interest, change in equity							145
Sempra Infrastructure \| SI Partners
Noncontrolling Interest [Line Items]
Increase in shareholders' equity						$ 709
Sale of noncontrolling interest, change in equity						710
Sale of noncontrolling interest, transaction costs						12
Reduction to deferred income tax liability						300
Sale of noncontrolling interest, transaction costs reimbursed						$ 10
KKR Denali \| Port Arthur LNG
Noncontrolling Interest [Line Items]
Increase in equity					$ 1,100
Increase in shareholders' equity					56
Sale of noncontrolling interest, transaction costs					11
Sale of noncontrolling interest, tax expense (tax benefit)					(22)
Indirect Subsidiary Of SI Partners \| Port Arthur LNG
Noncontrolling Interest [Line Items]
Cash consideration		254
Increase in shareholders' equity		12
Sale of noncontrolling interest, transaction costs		3
Sale of noncontrolling interest, tax expense (tax benefit)		5
Funding commitment, aggregate amount		$ 9,000
KKR \| SI Partners
Noncontrolling Interest [Line Items]
Funding commitment, aggregate amount															$ 200
Funding used							14		200
SI Partners \| KKR Denali \| Port Arthur LNG
Noncontrolling Interest [Line Items]
Cash consideration for minimum amount of interest transferred					984		$ 984		$ 984
Share of development costs incurred, threshold					$ 439
Port Arthur LNG \| Indirect Subsidiary Of SI Partners
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)		30.00%
Funding commitment (in percent)		110.00%
Guaranteed funding amount (in percent)		70.00%
Port Arthur LNG \| SI Partners \| KKR Denali
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					42.00%		42.00%		42.00%
Port Arthur LNG \| Minimum \| KKR Denali
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					19.60%		19.60%		19.60%
SI Partners \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					30.00%		30.00%		30.00%				30.00%
SI Partners \| Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest (as a percent)														10.00%
Sale of noncontrolling interest, aggregate purchase price														$ 1,700
SI Partners \| KKR
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)														20.00%	20.00%
SI Partners \| Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)														10.00%
SI Partners \| Sempra
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)														70.00%
SI Partners subsidiaries \| Minimum \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					0.10%		0.10%		0.10%				0.10%
SI Partners subsidiaries \| Maximum \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					42.00%		42.00%		42.00%				16.60%
Common stock
Noncontrolling Interest [Line Items]
Share repurchase program, number of shares repurchased (in shares) \| shares			2,943,914	2,945,512					411,447	404,806
Common stock repurchased									$ 32	$ 28
Accelerated share repurchase program, prepaid amount			$ 250	$ 200
Common stock repurchased, average price (in dollars per share) \| $ / shares			$ 84.92	$ 67.90

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

Sep. 30, 2023

Dec. 31, 2022

Sep. 30, 2022

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Cash and cash equivalents

$ 1,149

$ 370

^[1]

Restricted cash, current

238

^[1]

Restricted cash, noncurrent

104

^[1]

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

$ 1,491

$ 462

$ 786

$ 581

[1]	Derived from audited financial statements.

REVENUES (Tables)

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

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


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2023
By major service line:
Utilities	$	1,438	$	1,120	$	18	$	(35)	$	2,541
Energy-related businesses	—		—		369		(16)		353
Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894

By market:
Gas	$	182	$	1,120	$	234	$	(30)	$	1,506
Electric	1,256		—		153		(21)		1,388
Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894

Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894
Utilities regulatory revenues	4		193		—		—		197
Other revenues	—		—		242		1		243
Total revenues	$	1,442	$	1,313	$	629	$	(50)	$	3,334

	Nine months ended September 30, 2023
By major service line:
Utilities	$	4,603	$	6,252	$	67	$	(107)	$	10,815
Energy-related businesses	—		—		916		(56)		860
Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675

By market:
Gas	$	988	$	6,252	$	605	$	(95)	$	7,750
Electric	3,615		—		378		(68)		3,925
Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675

Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675
Utilities regulatory revenues	(246)		322		—		—		76
Other revenues	—		—		1,502		(24)		1,478
Total revenues	$	4,357	$	6,574	$	2,485	$	(187)	$	13,229


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2022
By major service line:
Utilities	$	1,383	$	1,214	$	19	$	(29)	$	2,587
Energy-related businesses	—		—		532		(13)		519
Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106

By market:
Gas	$	175	$	1,214	$	379	$	(30)	$	1,738
Electric	1,208		—		172		(12)		1,368
Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106

Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106
Utilities regulatory revenues	186		171		—		—		357
Other revenues	—		—		146		8		154
Total revenues	$	1,569	$	1,385	$	697	$	(34)	$	3,617

	Nine months ended September 30, 2022
By major service line:
Utilities	$	4,134	$	4,473	$	67	$	(85)	$	8,589
Energy-related businesses	—		—		1,281		(42)		1,239
Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828

By market:
Gas	$	664	$	4,473	$	948	$	(75)	$	6,010
Electric	3,470		—		400		(52)		3,818
Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828

Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828
Utilities regulatory revenues	279		406		—		—		685
Other revenues	—		—		462		9		471
Total revenues	$	4,413	$	4,879	$	1,810	$	(118)	$	10,984

Schedule of Timing of Remaining Performance Obligations

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


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first nine months of 2023)	$	85	$	1
2024	300		4
2025	338		4
2026	365		4
2027	365		4
Thereafter	4,077		59
Total revenues to be recognized	$	5,530	$	76

(1) Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the nine months ended September 30, 2023 or 2022. Sempra Infrastructure recorded a contract liability for funds held as collateral in lieu of a customer’s letters of credit associated with its LNG storage and regasification agreement.


CONTRACT LIABILITIES
(Dollars in millions)
	2023		2022
Sempra:
Contract liabilities at January 1	$	(252)	$	(278)
Revenue from performance obligations satisfied during reporting period	9		129
Payments received in advance	(21)		(105)
Contract liabilities at September 30(1)	$	(264)	$	(254)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	3		3
Contract liabilities at September 30(2)	$	(76)	$	(80)

(1) Balances at September 30, 2023 include $9 in Other Current Liabilities and $255 in Deferred Credits and Other.

(2) Balances at September 30, 2023 include $4 in Other Current Liabilities and $72 in Deferred Credits and Other.

Schedule of Contract Accounts Receivable

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


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	September 30, 2023		December 31, 2022
Sempra:
Accounts receivable – trade, net(1)	$	1,780	$	2,291
Accounts receivable – other, net	15		25
Due from unconsolidated affiliates – current(2)	5		9
Other long-term assets(3)	1		9
Total	$	1,801	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	952	$	799
Accounts receivable – other, net	13		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	1		6
Total	$	972	$	819
SoCalGas:
Accounts receivable – trade, net	$	665	$	1,295
Accounts receivable – other, net	2		13
Other long-term assets(3)	—		3
Total	$	667	$	1,311

(1) At September 30, 2023 and December 31, 2022, includes $201 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

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

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

CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Sep. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	629,328,058	628,669,356
San Diego Gas and Electric Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	116,583,358	116,583,358

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

3 Months Ended

9 Months Ended

Sep. 30, 2023

Sep. 30, 2022

Sep. 30, 2023

Sep. 30, 2022

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

Beginning balance

^[1]

$ 27,115

OCI before reclassifications

$ 111

$ 40

132

$ 162

Amounts reclassified from AOCI

(50)

(57)

Net OCI

198

Ending balance

28,238

Total accumulated other comprehensive income (loss)

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

Beginning balance

(121)

(167)

(135)

(318)

Ending balance

(60)

(120)

(60)

(120)

Foreign currency translation adjustments

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

Beginning balance

(38)

(65)

(59)

(79)

OCI before reclassifications

(5)

Amounts reclassified from AOCI

Net OCI

(5)

Ending balance

(43)

(65)

(43)

(65)

AOCI associated with noncontrolling interests

Financial instruments

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

Beginning balance

(30)

(156)

OCI before reclassifications

116

129

151

Amounts reclassified from AOCI

(51)

(60)

Net OCI

171

Ending balance

AOCI associated with noncontrolling interests

(46)

Pension and PBOP

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

Beginning balance

(97)

(72)

(86)

(83)

OCI before reclassifications

(13)

Amounts reclassified from AOCI

Net OCI

(10)

Ending balance

(96)

(70)

(96)

(70)

San Diego Gas and Electric Company

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

Beginning balance

^[1]

9,067

Amounts reclassified from AOCI

Net OCI

Ending balance

9,683

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

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

Beginning balance

(7)

(10)

(7)

(10)

Ending balance

(7)

(9)

(7)

(9)

San Diego Gas and Electric Company | Pension and PBOP

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

Beginning balance

(7)

(10)

(7)

(10)

Amounts reclassified from AOCI

Net OCI

Ending balance

(7)

(9)

(7)

(9)

Southern California Gas Company

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

Beginning balance

^[1]

6,698

Amounts reclassified from AOCI

Net OCI

Ending balance

7,231

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

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

Beginning balance

(22)

(29)

(24)

(31)

Ending balance

(22)

(28)

(22)

(28)

Southern California Gas Company | Financial instruments

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

Beginning balance

(11)

(12)

(13)

Amounts reclassified from AOCI

Net OCI

Ending balance

(11)

(12)

(11)

(12)

Southern California Gas Company | Pension and PBOP

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

Beginning balance

(11)

(17)

(12)

(18)

Amounts reclassified from AOCI

Net OCI

Ending balance

$ (11)

$ (16)

$ (11)

$ (16)

[1]	Derived from audited financial statements.

SEGMENT INFORMATION - NARRATIVE (Details)	9 Months Ended
SEGMENT INFORMATION - NARRATIVE (Details)	Sep. 30, 2023 segment
Segment Reporting Information [Line Items]
Number of reportable segments	4
Oncor Electric Delivery Company LLC Additional Acquisition \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	80.25%
Sharyland Holdings, LP \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest (in percent)	50.00%

CONDENSED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
REVENUES
Electric	$ 1,250	$ 1,357	$ 3,331	$ 3,663
Natural gas	1,488	1,587	7,560	5,611
Operating expenses:
Other Income (Expense), Net	3	(40)	75	(3)
Interest income	19	18	60	58
Interest expense	(312)	(282)	(995)	(796)
Income before income taxes and equity earnings	323	165	2,175	1,194
Income tax benefit (expense)	52	(21)	(499)	(435)
Net income	854	561	2,762	1,877
Earnings attributable to common shares	721	485	2,293	1,656
San Diego Gas and Electric Company
REVENUES
Electric	1,254	1,360	3,343	3,672
Natural gas	188	209	1,014	741
Operating revenues	1,442	1,569	4,357	4,413
Operating expenses:
Cost of electric fuel and purchased power	200	316	442	806
Cost of natural gas	45	65	462	260
Operation and maintenance	463	439	1,364	1,256
Depreciation and amortization	280	247	810	730
Franchise fees and other taxes	101	97	287	277
Total operating expenses	1,089	1,164	3,365	3,329
Operating income (loss)	353	405	992	1,084
Other Income (Expense), Net	25	12	75	68
Interest income	7	2	12	3
Interest expense	(126)	(113)	(367)	(333)
Income before income taxes and equity earnings	259	306	712	822
Income tax benefit (expense)	15	(35)	4	(141)
Net income	274	271	716	681
Earnings attributable to common shares	$ 274	$ 271	$ 716	$ 681

INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)

9 Months Ended

Sep. 30, 2023

Investments [Abstract]

Condensed Financial Statements

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


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Operating revenues	$	1,592	$	1,438	$	4,227	$	3,980
Operating expenses	(1,007)		(929)		(3,007)		(2,734)
Income from operations	585		509		1,220		1,246
Interest expense	(140)		(115)		(396)		(331)
Income tax expense	(81)		(70)		(148)		(164)
Net income	376		315		672		732
Noncontrolling interest held by Texas Transmission Investment LLC	(75)		(62)		(135)		(146)
Earnings attributable to Sempra(1)	301		253		537		586

(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.

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	1 Months Ended		9 Months Ended
	Oct. 31, 2020 GBP (£)	Mar. 31, 2020 GBP (£)	Sep. 30, 2023 USD ($)	Oct. 31, 2023 lawsuit claim
Plaintiffs \| HMRC VAT Claim
Loss Contingencies [Line Items]
Damages awarded		£ 45	$ 55
Cost and interest assessed	£ 21		$ 26
Energy Future Holdings Corp. \| Subsequent Event
Loss Contingencies [Line Items]
Lawsuits pending \| lawsuit				2
Number of proof of claims \| claim				28,000

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,762	$ 1,877
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,651	1,500
Deferred income taxes and investment tax credits	234	387
Equity earnings	(1,086)	(1,118)
Foreign currency transaction (gains) losses, net	(1)	18
Share-based compensation expense	53	49
Fixed-price contracts and other derivatives	(580)	200
Bad debt expense	368	110
Other	7	47
Reserve for Aliso Canyon costs	(3)	(1,835)
Net change in other working capital components	1,613	(267)
Insurance receivable for Aliso Canyon costs	0	350
Distributions from investments	668	643
Changes in other noncurrent assets and liabilities, net	(557)	(506)
Net cash provided by operating activities	5,129	1,455
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(6,074)	(3,540)
Expenditures for investments	(281)	(275)
Purchases of nuclear decommissioning and other trust assets	(462)	(530)
Proceeds from sales of nuclear decommissioning and other trust assets	503	530
Repayments of advances to unconsolidated affiliates	0	626
Other	10	6
Net cash used in investing activities	(6,304)	(3,183)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,109)	(1,070)
Preferred dividends paid	(22)	(22)
Issuances of common stock	0	4
Repurchases of common stock	(32)	(478)
Issuances of debt (maturities greater than 90 days)	6,911	6,711
Payments on debt (maturities greater than 90 days) and finance leases	(6,018)	(3,365)
Increase (decrease) in short-term debt, net	629	(1,438)
Advances from unconsolidated affiliates	31	28
Proceeds from sales of noncontrolling interests	1,238	1,732
Distributions to noncontrolling interests	(289)	(146)
Contributions from noncontrolling interests	1,036	15
Settlement of cross-currency swaps	(99)	0
Other	(78)	(35)
Net cash provided by financing activities	2,198	1,936
Effect of exchange rate changes on cash, cash equivalents and restricted cash	6	(3)
Increase in cash, cash equivalents and restricted cash	1,029	205
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, September 30	1,491	786
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	836	732
Income tax payments, net of refunds	162	241
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Repayment of advances from unconsolidated affiliate in lieu of distribution	36	32
Accrued capital expenditures	1,200	738
Increase in finance lease obligations for investment in PP&E	47	33
(Decrease) increase in ARO for investment in PP&E	(15)	49
Contributions from NCI	200	0
Sale of NCI post-closing adjustment payable	11	0
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	22	22
Common stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	$ 374	$ 360

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES NARRATIVE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (52)	$ 21	$ 499	$ 435
Deferred income tax liability for foreign earnings		120		120
Southern California Gas Company
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)	$ (5)	$ (28)	68	$ 75
Southern California Gas Company \| Cumulative Effect, Period of Adoption, Adjustment [Member]
Schedule Of Income Tax Expense And Effective Income Tax Rates [Line Items]
Income tax expense (benefit)			$ (43)

- Definition

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

+ References + Details

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

Sep. 30, 2023

Dec. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Dedicated assets in support of certain benefit plans

$ 513

$ 505

^[1]

[1]	Derived from audited financial statements.

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

Sep. 30, 2023

Dec. 31, 2022

Current assets:

Cash and cash equivalents

$ 1,149

$ 370

^[1]

Accounts receivable – trade, net

1,939

2,635

^[1]

Accounts receivable – other, net

498

685

^[1]

Due from unconsolidated affiliates

^[1]

Inventories

451

403

^[1]

Prepaid expenses

325

268

^[1]

Regulatory assets

190

351

^[1]

Fixed-price contracts and other derivatives

201

803

^[1]

Greenhouse gas allowances

144

141

^[1]

Other current assets

^[1]

Total current assets

5,310

5,912

^[1]

Other assets:

Regulatory assets

3,277

2,588

^[1]

Greenhouse gas allowances

1,219

796

^[1]

Nuclear decommissioning trusts

827

841

^[1]

Right-of-use assets – operating leases

721

655

^[1]

Wildfire fund

281

303

^[1]

Other long-term assets

1,874

1,382

^[1]

Total other assets

27,253

24,880

^[1]

Property, plant and equipment:

Property, plant and equipment

70,348

63,893

^[1]

Less accumulated depreciation and amortization

(17,176)

(16,111)

^[1]

Property, plant and equipment, net

53,172

47,782

^[1]

Total assets

85,735

78,574

^[1]

Current liabilities:

Short-term debt

1,977

3,352

^[1]

Accrued compensation and benefits

496

484

^[1]

Regulatory liabilities

529

504

^[1]

Current portion of long-term debt and finance leases

974

1,019

^[1]

Greenhouse gas obligations

144

141

^[1]

Total current liabilities

8,765

9,899

^[1]

Long-term debt and finance leases

27,703

24,548

^[1]

Deferred credits and other liabilities:

Regulatory liabilities

3,468

3,341

^[1]

Greenhouse gas obligations

942

565

^[1]

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

309

410

^[1]

Deferred income taxes

5,095

4,591

^[1]

Asset retirement obligations

3,584

3,546

^[1]

Deferred credits and other

2,308

2,117

^[1]

Total deferred credits and other liabilities

16,009

14,871

^[1]

Commitments and contingencies

^[1]

Equity:

Common stock

12,038

12,160

^[1]

Retained earnings

15,371

14,201

^[1]

Accumulated other comprehensive income (loss)

(60)

(135)

^[1]

Total shareholders’ equity

28,238

27,115

^[1]

Total liabilities and equity

85,735

78,574

^[1]

Related Party

Current assets:

Due from unconsolidated affiliates

Current liabilities:

Other current liabilities

^[1]

Nonrelated Party

Current liabilities:

Other current liabilities

1,327

1,380

^[1]

San Diego Gas and Electric Company

Current assets:

Cash and cash equivalents

246

^[1]

Accounts receivable – trade, net

952

799

^[1]

Accounts receivable – other, net

155

110

^[1]

Due from unconsolidated affiliates

^[1]

Inventories

147

134

^[1]

Prepaid expenses

196

179

^[1]

Regulatory assets

247

^[1]

Fixed-price contracts and other derivatives

113

^[1]

Greenhouse gas allowances

^[1]

Other current assets

^[1]

Total current assets

1,854

1,630

^[1]

Other assets:

Regulatory assets

1,694

1,219

^[1]

Greenhouse gas allowances

251

196

^[1]

Nuclear decommissioning trusts

827

841

^[1]

Right-of-use assets – operating leases

364

281

^[1]

Wildfire fund

281

303

^[1]

Other long-term assets

143

146

^[1]

Total other assets

3,560

2,986

^[1]

Property, plant and equipment:

Property, plant and equipment

30,304

28,574

^[1]

Less accumulated depreciation and amortization

(7,216)

(6,768)

^[1]

Property, plant and equipment, net

23,088

21,806

^[1]

Total assets

28,502

26,422

^[1]

Current liabilities:

Short-term debt

205

^[1]

Accounts payable

854

744

^[1]

Interest payable

111

^[1]

Accrued compensation and benefits

138

140

^[1]

Accrued franchise fees

103

120

^[1]

Regulatory liabilities

300

110

^[1]

Current portion of long-term debt and finance leases

441

489

^[1]

Greenhouse gas obligations

^[1]

Asset retirement obligations

110

^[1]

Total current liabilities

2,458

2,319

^[1]

Long-term debt and finance leases

9,453

8,497

^[1]

Deferred credits and other liabilities:

Regulatory liabilities

2,417

2,298

^[1]

Greenhouse gas obligations

130

^[1]

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

^[1]

Deferred income taxes

2,596

2,540

^[1]

Asset retirement obligations

772

789

^[1]

Deferred credits and other

966

789

^[1]

Total deferred credits and other liabilities

6,908

6,539

^[1]

Commitments and contingencies

^[1]

Equity:

Preferred stock

^[1]

Common stock

1,660

^[1]

Retained earnings

8,030

7,414

^[1]

Accumulated other comprehensive income (loss)

(7)

^[1]

Total shareholders’ equity

9,683

9,067

^[1]

Total liabilities and equity

28,502

26,422

^[1]

San Diego Gas and Electric Company | Related Party

Current assets:

Due from unconsolidated affiliates

Current liabilities:

Other current liabilities

135

^[1]

San Diego Gas and Electric Company | Nonrelated Party

Current liabilities:

Other current liabilities

$ 330

$ 193

^[1]

[1]	Derived from audited financial statements.

CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,762	$ 1,877
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,651	1,500
Deferred income taxes and investment tax credits	234	387
Bad debt expense	368	110
Other	7	47
Net change in other working capital components	1,613	(267)
Changes in other noncurrent assets and liabilities, net	(557)	(506)
Net cash provided by operating activities	5,129	1,455
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(6,074)	(3,540)
Purchases of nuclear decommissioning and other trust assets	(462)	(530)
Proceeds from sales of nuclear decommissioning and other trust assets	503	530
Other	10	6
Net cash used in investing activities	(6,304)	(3,183)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,109)	(1,070)
Issuances of debt (maturities greater than 90 days)	6,911	6,711
Payments on debt (maturities greater than 90 days) and finance leases	(6,018)	(3,365)
Increase in short-term debt, net	629	(1,438)
Net cash provided by financing activities	2,198	1,936
Increase in cash, cash equivalents and restricted cash	1,029	205
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, September 30	1,491	786
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	836	732
Income tax payments, net of refunds	162	241
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,200	738
Increase in finance lease obligations for investment in PP&E	47	33
(Decrease) increase in ARO for investment in PP&E	(15)	49
San Diego Gas and Electric Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	716	681
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	810	730
Deferred income taxes and investment tax credits	(56)	91
Bad debt expense	94	46
Other	(30)	(23)
Net change in other working capital components	269	57
Changes in other noncurrent assets and liabilities, net	(319)	(214)
Net cash provided by operating activities	1,484	1,368
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,893)	(1,651)
Purchases of nuclear decommissioning and other trust assets	(391)	(530)
Proceeds from sales of nuclear decommissioning and other trust assets	437	530
Other	9	8
Net cash used in investing activities	(1,838)	(1,643)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(100)	(100)
Issuances of debt (maturities greater than 90 days)	1,389	1,395
Payments on debt (maturities greater than 90 days) and finance leases	(479)	(416)
Increase in short-term debt, net	(205)	(401)
Debt issuance costs	(12)	(9)
Net cash provided by financing activities	593	469
Increase in cash, cash equivalents and restricted cash	239	194
Cash, cash equivalents and restricted cash, January 1	7	25
Cash, cash equivalents and restricted cash, September 30	246	219
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	315	303
Income tax payments, net of refunds	0	68
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	237	236
Increase in finance lease obligations for investment in PP&E	7	12
(Decrease) increase in ARO for investment in PP&E	$ 13	$ 1

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions	1 Months Ended			3 Months Ended		4 Months Ended	9 Months Ended		12 Months Ended	25 Months Ended	48 Months Ended
	Oct. 31, 2023 plaintiff	Sep. 30, 2021 USD ($) lawsuit plaintiff	Jan. 31, 2021 lawsuit	Sep. 30, 2023 USD ($) lawsuit	Sep. 30, 2022 USD ($)	Feb. 11, 2016 well	Sep. 30, 2023 USD ($) segment lawsuit	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Oct. 31, 2023 plaintiff	Dec. 31, 2021 lawsuit claimant	Aug. 31, 2023 Bcf	Nov. 30, 2021 Bcf	Mar. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Liability for legal proceedings				$ 203			$ 203
Natural gas inventory level (in bcf) \| Bcf												68.6	41.16
Aliso Canyon litigation and regulatory matters				0	$ 122		$ 0	$ 259
Number of reportable segments \| segment							4
Sempra Infrastructure
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit														3
Number of claimants \| claimant											3
Number of reportable segments \| segment							2
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings				125			$ 125
Southern California Gas Company
Loss Contingencies [Line Items]
Liability for legal proceedings				127			127
Wells with gas leak \| well						1
Aliso Canyon litigation and regulatory matters				0	122		0	259
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings				125			125
Number of lawsuits \| lawsuit		390
Number of plaintiffs \| plaintiff		36,000
Net book value of Aliso Canyon facility				993			993
Aliso Canyon litigation and regulatory matters, net of tax					$ 101			$ 199
Reserve for Aliso Canyon costs				$ 126			$ 126
Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff	233
Southern California Gas Company \| Shareholder Derivative Complaint
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit				4			4
Claims dismissed \| lawsuit			3
Southern California Gas Company \| Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs		$ 1,800
Percentage of plaintiffs agreeing to participate and submit releases (in percent)									99.00%
Payment of liquidating companies' costs									$ 1,790
Southern California Gas Company \| The Developer Plaintiffs \| Aliso Canyon Natural Gas Storage Facility Gas Leak \| Subsequent Event
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff										394
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit											2
Deferred Credits and Other \| Southern California Gas Company \| Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Reserve for Aliso Canyon costs				$ 3			$ 3

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (252)	$ (278)
Revenue from performance obligations satisfied during reporting period	9	129
Payments received in advance	(21)	(105)
Contract liabilities, closing balance	(264)	(254)
Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(9)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(255)
San Diego Gas and Electric Company
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(79)	(83)
Revenue from performance obligations satisfied during reporting period	3	3
Contract liabilities, closing balance	(76)	$ (80)
San Diego Gas and Electric Company \| Other current liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(4)
San Diego Gas and Electric Company \| Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ (72)

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income	$ 854	$ 561	$ 2,762	$ 1,877
Other comprehensive income (loss):
Foreign currency translation adjustments	(7)	(1)	22	5
Financial instruments	315	66	321	227
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive income	309	67	333	245
Comprehensive income	1,163	628	3,095	2,122
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income			3,094	2,121
Pretax amount
Net income	680	517	2,826	2,125
Other comprehensive income (loss):
Foreign currency translation adjustments	(5)	0	16	5
Financial instruments	150	60	158	227
Pension and other postretirement benefits	2	2	(8)	15
Total other comprehensive income	147	62	166	247
Comprehensive income	827	579	2,992	2,372
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income			2,991	2,371
Income tax benefit (expense)
Net income	52	(21)	(499)	(435)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0	0
Financial instruments	(39)	(15)	(43)	(56)
Pension and other postretirement benefits	(1)	0	(2)	(2)
Total other comprehensive income	(40)	(15)	(45)	(58)
Comprehensive income	12	(36)	(544)	(493)
Preferred dividends of subsidiary			0	0
Comprehensive income			(544)	(493)
Net-of-tax amount
Net income	732	496	2,327	1,690
Other comprehensive income (loss):
Foreign currency translation adjustments	(5)	0	16	5
Financial instruments	111	45	115	171
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive income	107	47	121	189
Comprehensive income	839	543	2,448	1,879
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income			2,447	1,878
Noncontrolling interests (after tax)
Net income	122	65	435	187
Other comprehensive income (loss):
Foreign currency translation adjustments	(2)	(1)	6	0
Financial instruments	204	21	206	56
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive income	202	20	212	56
Comprehensive income	$ 324	$ 85	647	243
Preferred dividends of subsidiary			0	0
Comprehensive income			$ 647	$ 243

FAIR VALUE MEASUREMENTS

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

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

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

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

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

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

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

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

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


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	21	$	3	$	—	$	24
Equity securities	291		4		—		295
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		16		—		43
Municipal bonds	—		260		—		260
Other securities	—		216		—		216
Total debt securities	27		492		—		519
Total nuclear decommissioning trusts(1)	339		499		—		838
Short-term investments held in Rabbi Trust	62		—		—		62
Interest rate instruments	—		378		—		378
Foreign exchange instruments	—		1		—		1
Commodity contracts not subject to rate recovery	—		12		—		12
Effect of netting and allocation of collateral(2)	89		—		—		89
Commodity contracts subject to rate recovery	—		—		18		18
Effect of netting and allocation of collateral(2)	76		—		6		82
Support Agreement, net of related guarantee fees	—		—		18		18
Total	$	566	$	890	$	42	$	1,498
Liabilities:
Foreign exchange instruments	$	—	$	8	$	—	$	8
Commodity contracts not subject to rate recovery	—		13		—		13
Commodity contracts subject to rate recovery	2		156		—		158
Effect of netting and allocation of collateral(2)	(1)		—		—		(1)
Total	$	1	$	177	$	—	$	178

(1) Excludes receivables (payables), net.

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


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

1) Excludes receivables (payables), net.

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


RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	21	$	3	$	—	$	24
Equity securities	291		4		—		295
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		16		—		43
Municipal bonds	—		260		—		260
Other securities	—		216		—		216
Total debt securities	27		492		—		519
Total nuclear decommissioning trusts(1)	339		499		—		838
Commodity contracts subject to rate recovery	—		—		18		18
Effect of netting and allocation of collateral(2)	74		—		6		80
Total	$	413	$	499	$	24	$	936
Liabilities:
Commodity contracts subject to rate recovery	$	2	$	—	$	—	$	2
Effect of netting and allocation of collateral(2)	(1)		—		—		(1)
Total	$	1	$	—	$	—	$	1

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

(1) Excludes receivables (payables), net.

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


RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Effect of netting and allocation of collateral(1)	$	2	$	—	$	—	$	2
Total	$	2	$	—	$	—	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	156	$	—	$	156
Total	$	—	$	156	$	—	$	156

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

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

Level 3 Information

SDG&E

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


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended September 30,
	2023		2022
Balance at July 1	$	20	$	33
Realized and unrealized losses	(2)		(35)
Allocated transmission instruments	1		2
Settlements	(1)		33
Balance at September 30	$	18	$	33
Change in unrealized gains relating to instruments still held at September 30	$	1	$	3

	Nine months ended September 30,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized losses	(10)		(58)
Allocated transmission instruments	(1)		(4)
Settlements	(6)		41
Balance at September 30	$	18	$	33
Change in unrealized losses relating to instruments still held at September 30	$	(8)	$	(15)

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

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

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


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

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

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

Long-term, fixed-price electricity positions in 2022 that were valued using significant unobservable data were classified as Level 3 because the contract terms related to a delivery location or tenor for which observable market rate information was not available. The fair value of the net electricity positions classified as Level 3 was derived from a discounted cash flow model using market electricity forward price inputs. The range and weighted-average price of these inputs at September 30, 2022 were $26.75 to $127.20 and $68.50, respectively. We summarize long-term, fixed-price electricity position volumes in Note 7.

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

Sempra Infrastructure

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


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended September 30,
	2023		2022
Balance at July 1	$	23	$	16
Realized and unrealized (losses) gains(1)	(3)		2
Settlements	(2)		(2)
Balance at September 30(2)	$	18	$	16
Change in unrealized (losses) gains relating to instruments still held at September 30	$	(2)	$	2

	Nine months ended September 30,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	7		16
Settlements	(6)		(7)
Balance at September 30(2)	$	18	$	16
Change in unrealized gains relating to instruments still held at September 30	$	7	$	15

(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 $11 in Other Long-term Assets at September 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet.

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

Fair Value of Financial Instruments

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


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

Long-term note receivable(1)	$	330	$	—	$	—	$	295	$	295
Long-term amounts due to unconsolidated affiliates	308		—		269		—		269
Total long-term debt(2)	27,657		—		23,765		—		23,765
SDG&E:
Total long-term debt(3)	$	8,750	$	—	$	7,202	$	—	$	7,202
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	5,953	$	—	$	5,953

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

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

(2) Before reductions of unamortized discount and debt issuance costs of $326 and $289 at September 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,346 and $1,343 at September 30, 2023 and December 31, 2022, respectively.

(3) Before reductions of unamortized discount and debt issuance costs of $90 and $70 at September 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $1,234 and $1,256 at September 30, 2023 and December 31, 2022, respectively.

(4) Before reductions of unamortized discount and debt issuance costs of $57 and $48 at September 30, 2023 and December 31, 2022, respectively, and excluding finance lease obligations of $112 and $87 at September 30, 2023 and December 31, 2022, respectively.

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

- Definition

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

+ References + Details

SEGMENT INFORMATION

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

SEGMENT INFORMATION

We have four separately managed reportable segments, as follows:

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

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

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

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

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

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

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


SEGMENT INFORMATION
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
REVENUES
SDG&E	$	1,442	$	1,569	$	4,357	$	4,413
SoCalGas	1,313		1,385		6,574		4,879
Sempra Infrastructure	629		697		2,485		1,810
All other	—		1		—		1
Adjustments and eliminations	—		—		(1)		—
Intersegment revenues(1)	(50)		(35)		(186)		(119)
Total	$	3,334	$	3,617	$	13,229	$	10,984
DEPRECIATION AND AMORTIZATION
SDG&E	$	280	$	247	$	810	$	730
SoCalGas	211		190		625		565
Sempra Infrastructure	71		67		210		199
All other	1		2		6		6
Total	$	563	$	506	$	1,651	$	1,500
INTEREST INCOME
SDG&E	$	7	$	2	$	12	$	3
SoCalGas	2		3		7		4
Sempra Infrastructure	4		7		25		37
All other	7		6		17		14
Intercompany eliminations	(1)		—		(1)		—
Total	$	19	$	18	$	60	$	58
INTEREST EXPENSE
SDG&E	$	126	$	113	$	367	$	333
SoCalGas	70		50		210		135
Sempra Infrastructure	7		39		127		98
All other	109		81		292		232
Intercompany eliminations	—		(1)		(1)		(2)
Total	$	312	$	282	$	995	$	796
INCOME TAX (BENEFIT) EXPENSE
SDG&E	$	(15)	$	35	$	(4)	$	141
SoCalGas	(5)		(28)		68		75
Sempra Texas Utilities	—		1		—		1
Sempra Infrastructure	24		58		555		219
All other	(56)		(45)		(120)		(1)
Total	$	(52)	$	21	$	499	$	435
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	1	$	5	$	6
Sempra Infrastructure	131		133		413		430

	133		134		418		436
Equity earnings, net of income tax:
Sempra Texas Utilities	305		257		548		603
Sempra Infrastructure	41		26		120		79
	346		283		668		682
Total	$	479	$	417	$	1,086	$	1,118

(1) Revenues for reportable segments include intersegment revenues of $5, $29, and $16 for the three months ended September 30, 2023 and $14, $91, and $81 for the nine months ended September 30, 2023; $4, $24, and $7 for the three months ended September 30, 2022 and $11, $73, and $35 for the nine months ended September 30, 2022 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	274	$	271	$	716	$	681
SoCalGas	16		(82)		531		339
Sempra Texas Utilities	305		256		548		604
Sempra Infrastructure	223		114		746		392
All other	(97)		(74)		(248)		(360)
Total	$	721	$	485	$	2,293	$	1,656
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,893	$	1,651
SoCalGas					1,451		1,394
Sempra Infrastructure					2,725		489
All other					5		6
Total					$	6,074	$	3,540

					September 30, 2023		December 31, 2022
ASSETS
SDG&E					$	28,502	$	26,422
SoCalGas					23,069		22,346
Sempra Texas Utilities					14,269		13,781
Sempra Infrastructure					19,722		15,760
All other					1,205		1,376
Intersegment receivables					(1,032)		(1,111)
Total					$	85,735	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities					$	14,260	$	13,772
Sempra Infrastructure					2,096		1,905
Total					$	16,356	$	15,677

- Definition

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.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 22
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-22

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 15
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-15

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 31
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-31

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 32
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-32

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 42
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-42

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 32
-Subparagraph (f)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-32

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 40
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-40

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org//280/tableOfContent

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 26
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-26

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 34
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-34

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 41
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-41

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 21
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-21

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 21
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-21

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 32
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-32

+ Details

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,801	$ 2,334
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,780	2,291
Accounts receivable – trade, net \| Community Choice Aggregation
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	201	72
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	15	25
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	5	9
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1	9
San Diego Gas and Electric Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	972	819
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	952	799
San Diego Gas and Electric Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	13	12
San Diego Gas and Electric Company \| Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	2
San Diego Gas and Electric Company \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1	6
Southern California Gas Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	667	1,311
Southern California Gas Company \| Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	665	1,295
Southern California Gas Company \| Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	13
Southern California Gas Company \| Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 0	$ 3

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($) $ / MWh	Sep. 30, 2023 USD ($) $ / MWh	Sep. 30, 2022 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 20	$ 33	$ 35	$ 54
Realized and unrealized losses	(2)	(35)	(10)	(58)
Allocated transmission instruments	1	2	(1)	(4)
Settlements	(1)	33	(6)	41
Ending balance	18	33	18	33
Change in unrealized losses relating to instruments still held at September 30	1	3	(8)	(15)
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	23	16	17	7
Realized and unrealized gains	(3)	2	7	16
Settlements	(2)	(2)	(6)	(7)
Ending balance	18	16	18	16
Change in unrealized gains (losses) relating to instruments still held at the end of the period	(2)	2	7	15
Sempra Infrastructure \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7		7
Sempra Infrastructure \| Other long-term assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	11		11
San Diego Gas and Electric Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	20	33	35	54
Realized and unrealized losses	(2)	(35)	(10)	(58)
Allocated transmission instruments	1	2	(1)	(4)
Settlements	(1)	33	(6)	41
Ending balance	18	33	18	33
Change in unrealized losses relating to instruments still held at September 30	$ 1	$ 3	$ (8)	$ (15)
Level 3 \| San Diego Gas and Electric Company \| Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(3.09)	(3.67)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh		26.75		26.75
Level 3 \| San Diego Gas and Electric Company \| Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			10.71	6.96
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh		127.20		127.20
Level 3 \| San Diego Gas and Electric Company \| Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh			(0.56)	(0.70)
Market electricity forward price inputs ( in dollars per MWH) \| $ / MWh		68.50		68.50

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, 2021

$ 27,419

$ 889

$ 11,862

$ 13,548

$ (318)

$ 25,981

$ 1,438

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

Net income

1,877

1,690

187

Other comprehensive (loss) income

245

189

Share-based compensation expense

Dividends declared:

Preferred dividends

$ (33)

Common stock dividends declared

(1,081)

Preferred dividends of subsidiary

(1)

Issuances of common stock

Repurchases of common stock

(478)

Noncontrolling interest activities:

Contributions

Distributions

(146)

Sale

1,419

701

710

709

Ending balance at Sep. 30, 2022

29,289

889

12,138

14,123

(120)

27,030

2,259

Beginning Balance at Jun. 30, 2022

29,053

889

12,121

13,998

(167)

26,841

2,212

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

Net income

561

496

Other comprehensive (loss) income

Share-based compensation expense

Dividends declared:

Preferred dividends

(11)

Common stock dividends declared

(360)

Issuances of common stock

Repurchases of common stock

(2)

Noncontrolling interest activities:

Contributions

Distributions

(40)

Sale

Ending balance at Sep. 30, 2022

29,289

889

12,138

14,123

(120)

27,030

2,259

Beginning Balance at Dec. 31, 2022

29,256

^[1]

889

12,160

14,201

(135)

27,115

2,141

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

Net income

2,762

2,327

435

Other comprehensive (loss) income

333

121

212

Share-based compensation expense

Dividends declared:

Preferred dividends

(33)

Common stock dividends declared

(1,123)

Preferred dividends of subsidiary

(1)

Repurchases of common stock

(32)

Noncontrolling interest activities:

Contributions

1,091

(145)

1,236

Distributions

(289)

Sale

1,241

(46)

(44)

1,285

Ending balance at Sep. 30, 2023

33,258

889

12,038

15,371

(60)

28,238

5,020

Beginning Balance at Jun. 30, 2023

31,014

889

12,044

15,024

(121)

27,836

3,178

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

Net income

854

732

122

Other comprehensive (loss) income

309

107

202

Share-based compensation expense

Dividends declared:

Preferred dividends

$ (11)

Common stock dividends declared

(374)

Repurchases of common stock

(1)

Noncontrolling interest activities:

Contributions

496

(11)

507

Distributions

(37)

Sale

986

(16)

(46)

(62)

1,048

Ending balance at Sep. 30, 2023

$ 33,258

$ 889

$ 12,038

$ 15,371

$ (60)

$ 28,238

$ 5,020

[1]	Derived from audited financial statements.

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Allowance for credit losses	$ 6	$ 7
Unamortized transaction costs	4	5
Unamortized discount and debt issuance costs	326	289
Finance lease obligations	1,346	1,343
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	330	318
Long-term amounts due to unconsolidated affiliates	308	301
Total long-term debt	27,657	24,513
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	295	286
Long-term amounts due to unconsolidated affiliates	269	263
Total long-term debt	23,765	21,549
Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliates	269	263
Total long-term debt	23,765	21,549
Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term notes receivable	295	286
Long-term amounts due to unconsolidated affiliates	0	0
Total long-term debt	0	0
San Diego Gas and Electric Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	90	70
Finance lease obligations	1,234	1,256
San Diego Gas and Electric Company \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	8,750	7,800
San Diego Gas and Electric Company \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,202	6,726
San Diego Gas and Electric Company \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
San Diego Gas and Electric Company \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,202	6,726
San Diego Gas and Electric Company \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	57	48
Finance lease obligations	112	87
Southern California Gas Company \| Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,759	6,059
Southern California Gas Company \| Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,953	5,538
Southern California Gas Company \| Fair value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Southern California Gas Company \| Fair value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,953	5,538
Southern California Gas Company \| Fair value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2023 MMBTU MWh	Dec. 31, 2022 MMBTU MWh
Natural gas \| Long
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	441	254
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	40	42
SDG&E \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	16	15
SDG&E \| Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MWh	40	42
SoCalGas \| Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount \| MMBTU	347	224

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SoCalGas - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income	$ 854	$ 561	$ 2,762	$ 1,877
Other comprehensive income (loss):
Financial instruments	315	66	321	227
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive income	309	67	333	245
Comprehensive income			3,094	2,121
Pretax amount
Net income	680	517	2,826	2,125
Other comprehensive income (loss):
Financial instruments	150	60	158	227
Pension and other postretirement benefits	2	2	(8)	15
Total other comprehensive income	147	62	166	247
Comprehensive income			2,991	2,371
Income tax benefit (expense)
Net income	52	(21)	(499)	(435)
Other comprehensive income (loss):
Financial instruments	(39)	(15)	(43)	(56)
Pension and other postretirement benefits	(1)	0	(2)	(2)
Total other comprehensive income	(40)	(15)	(45)	(58)
Comprehensive income			(544)	(493)
Net-of-tax amount
Net income	732	496	2,327	1,690
Other comprehensive income (loss):
Financial instruments	111	45	115	171
Pension and other postretirement benefits	1	2	(10)	13
Total other comprehensive income	107	47	121	189
Comprehensive income			2,447	1,878
Southern California Gas Company
Net income	16	(82)	532	340
Other comprehensive income (loss):
Total other comprehensive income		1	2	3
Southern California Gas Company \| Pretax amount
Net income	11	(110)	600	415
Other comprehensive income (loss):
Financial instruments			1	1
Pension and other postretirement benefits	1	1	2	2
Total other comprehensive income	1	1	3	3
Comprehensive income	12	(109)	603	418
Southern California Gas Company \| Income tax benefit (expense)
Net income	5	28	(68)	(75)
Other comprehensive income (loss):
Financial instruments			0	0
Pension and other postretirement benefits	(1)	0	(1)	0
Total other comprehensive income	(1)	0	(1)	0
Comprehensive income	4	28	(69)	(75)
Southern California Gas Company \| Net-of-tax amount
Net income	16	(82)	532	340
Other comprehensive income (loss):
Financial instruments			1	1
Pension and other postretirement benefits	0	1	1	2
Total other comprehensive income	0	1	2	3
Comprehensive income	$ 16	$ (81)	$ 534	$ 343

SAN ONOFRE NUCLEAR GENERATING STATION

9 Months Ended

Sep. 30, 2023

Regulated Operations [Abstract]

SAN ONOFRE NUCLEAR GENERATING STATION

REGULATORY MATTERS

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


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

SDG&E:
Fixed-price contracts and other derivatives	$	(10)	$	(110)
Deferred income taxes recoverable in rates	518		296
Pension and PBOP plan obligations	(2)		11
Removal obligations	(2,382)		(2,248)
Environmental costs	105		107
Sunrise Powerlink fire mitigation	123		123
Regulatory balancing accounts(1)(2):
Commodity – electric	111		220
Gas transportation	15		60
Safety and reliability	186		107
Public purpose programs	(133)		(69)
Wildfire mitigation plan	607		375
Liability insurance premium	96		99
Other balancing accounts	(338)		(50)
Other regulatory assets, net(2)	96		137
Total SDG&E	(1,008)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	244		161
Pension and PBOP plan obligations	(265)		(170)
Employee benefit costs	24		24
Removal obligations	(597)		(616)
Environmental costs	39		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(356)		(257)
Safety and reliability	691		575
Public purpose programs	(149)		(158)
Liability insurance premium	23		23
Other balancing accounts	519		115
Other regulatory assets, net(2)	224		223
Total SoCalGas	397		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	3		—
Total Sempra Infrastructure	81		78
Total Sempra	$	(530)	$	(906)

(1) At September 30, 2023 and December 31, 2022, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $842 and $562, respectively, and for SoCalGas was $957 and $692, respectively.

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

SEMPRA CALIFORNIA

CPUC GRC

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

In May 2022, SDG&E and SoCalGas filed their 2024 GRC applications requesting CPUC approval of test year revenue requirements for 2024 and attrition year adjustments for 2025 through 2027. SDG&E and SoCalGas requested revenue requirements for 2024 of $3.0 billion and $4.4 billion, respectively. SDG&E and SoCalGas proposed post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 11% at SDG&E and approximately 6% to 8% at SoCalGas. Intervening parties have proposed various adjustments to SDG&E’s and SoCalGas’ revenue requirement requests. In October 2022, the CPUC issued a scoping ruling that set a schedule for the proceeding, including the expected issuance of a proposed decision in the second quarter of 2024. The CPUC has authorized SDG&E and SoCalGas to recognize the effects of the GRC final decision retroactive to January 1, 2024. In October 2023, SDG&E submitted a separate request with the CPUC in its 2024 GRC describing $2.2 billion in costs to implement its wildfire mitigation plans from 2019 through 2022, and seeking review and recovery of the incremental wildfire mitigation plan costs incurred during that period, totaling $1.5 billion. SDG&E expects to receive a proposed decision on this request in the second half of 2024. SDG&E also expects to submit in mid-2024 a separate request in its 2024 GRC for review and recovery of its wildfire mitigation plan costs incurred in 2023. The results of the GRC may materially and adversely differ from what is contained in the GRC applications.

CPUC Cost of Capital

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


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

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

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

The CCM was triggered for SDG&E and SoCalGas on September 30, 2023 and, subject to regulatory approval, would increase each of their authorized rates of return effective January 1, 2024 as follows:


PROPOSED CPUC 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	%

SDG&E

FERC Rate Matters

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

SAN ONOFRE NUCLEAR GENERATING STATION

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

NUCLEAR DECOMMISSIONING AND FUNDING

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to 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 2022, the CPUC granted SDG&E authorization to access NDT funds of up to $81 million for forecasted 2023 costs.

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


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	September 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	44	$	1	$	(2)	$	43
Municipal bonds(2)	278		—		(18)		260
Other securities(3)	234		1		(19)		216
Total debt securities	556		2		(39)		519
Equity securities	99		201		(5)		295
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(11)		—		—		(11)
Total	$	668	$	203	$	(44)	$	827

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

(1) Maturity dates are 2023-2054.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Proceeds from sales	$	143	$	133	$	437	$	530
Gross realized gains	12		2		20		16
Gross realized losses	(3)		(3)		(9)		(14)

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 $512 million at September 30, 2023 and is based on a cost study prepared in 2020 that is pending CPUC approval. SDG&E expects to receive a proposed decision in the fourth quarter of 2023.

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (530)	$ (906)
San Diego Gas and Electric Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	842	562
San Diego Gas and Electric Company \| Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(10)	(110)
San Diego Gas and Electric Company \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	518	296
San Diego Gas and Electric Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2)	11
San Diego Gas and Electric Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,382)	(2,248)
San Diego Gas and Electric Company \| Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	105	107
San Diego Gas and Electric Company \| Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	123	123
San Diego Gas and Electric Company \| Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	111	220
San Diego Gas and Electric Company \| Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	15	60
San Diego Gas and Electric Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	186	107
San Diego Gas and Electric Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(133)	(69)
San Diego Gas and Electric Company \| Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	607	375
San Diego Gas and Electric Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	96	99
San Diego Gas and Electric Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(338)	(50)
San Diego Gas and Electric Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	96	137
San Diego Gas and Electric Company \| Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,008)	(942)
Southern California Gas Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	957	692
Southern California Gas Company \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	244	161
Southern California Gas Company \| Pension and PBOP plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(265)	(170)
Southern California Gas Company \| Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(597)	(616)
Southern California Gas Company \| Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	24	24
Southern California Gas Company \| Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	39	38
Southern California Gas Company \| Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(356)	(257)
Southern California Gas Company \| Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	691	575
Southern California Gas Company \| Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(149)	(158)
Southern California Gas Company \| Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	23	23
Southern California Gas Company \| Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	519	115
Southern California Gas Company \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	224	223
Southern California Gas Company \| Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	397	(42)
Sempra Infrastructure \| Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	78	78
Sempra Infrastructure \| Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	3	0
Sempra Infrastructure \| Total Sempra Infrastructure
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 81	$ 78

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

COVER - shares	9 Months Ended
COVER - shares	Sep. 30, 2023	Oct. 31, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		629,328,058
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company
Document Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8330 Century Park Court
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92123
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000086521
Southern California Gas Company
Document Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West 5th Street
Entity Address, City or Town	Los Angeles
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90013
City Area Code	(213)
Local Phone Number	244-1200
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000092108
Common stock
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
5.75% Junior Subordinated Notes Due 2079
Document Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - San Diego Gas and Electric Company - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Jointly Owned Nuclear Power Plant
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20.00%
Percent of dismantlement work expense (as a percent)	20.00%
ARO related to decommissioning costs	$ 512
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 81

GENERAL INFORMATION AND OTHER FINANCIAL DATA

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

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

SDG&E

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

SoCalGas

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

BASIS OF PRESENTATION

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

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

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

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

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

Regulated Operations

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

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

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

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

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

Restricted cash includes:

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

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

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


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	September 30, 2023		December 31, 2022
Cash and cash equivalents	$	1,149	$	370
Restricted cash, current	238		40
Restricted cash, noncurrent	104		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	1,491	$	462

CREDIT LOSSES

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

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

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

As a result of the impact and duration of suspending collections processes during the COVID-19 pandemic, the implementation of programs such as the Arrearage Management Plan, and higher winter season customer billings, certain SDG&E and SoCalGas customers exhibit slower payment and higher levels of nonpayment than has been the case historically. This in turn has resulted in an increase in provisions for expected credit losses in the nine months ended September 30, 2023 for both companies, even as collections processes resume and past due payments potentially begin increasing. 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 of the Notes to Consolidated Financial Statements in the Annual Report and herein.

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


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2023		2022
Sempra:
Allowances for credit losses at January 1	$	181	$	136
Provisions for expected credit losses	374		111
Write-offs	(74)		(57)
Allowances for credit losses at September 30	$	481	$	190
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	96		51
Write-offs	(34)		(30)
Allowances for credit losses at September 30	$	140	$	87
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	276		58
Write-offs	(40)		(27)
Allowances for credit losses at September 30	$	334	$	100

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


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	September 30,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	432	$	140
Accounts receivable – other, net	48		40
Other long-term assets	1		1
Total allowances for credit losses	$	481	$	181
SDG&E:
Accounts receivable – trade, net	$	113	$	52
Accounts receivable – other, net	26		25
Other long-term assets	1		1
Total allowances for credit losses	$	140	$	78
SoCalGas:
Accounts receivable – trade, net	$	312	$	83
Accounts receivable – other, net	22		15
Total allowances for credit losses	$	334	$	98

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

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

INVENTORIES

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Natural gas	$	160	$	106	$	1	$	1	$	144	$	74
LNG	9		62		—		—		—		—
Materials and supplies	282		235		146		133		116		85
Total	$	451	$	403	$	147	$	134	$	260	$	159

NOTE RECEIVABLE

In November 2021, Sempra loaned $300 million to KKR Pinnacle in exchange for an interest-bearing promissory note that is due in full no later than October 2029 and bears compound interest at 5% per annum, which may be paid quarterly or added to the outstanding principal at the election of KKR Pinnacle. At September 30, 2023 and December 31, 2022, Other Long-Term Assets includes $328 million and $316 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, on Sempra’s Condensed Consolidated Balance Sheets.

WILDFIRE FUND

In July 2019, the Wildfire Legislation was signed into law to address certain issues related to catastrophic wildfires in the State of 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.

In October 2023, the OEIS approved SDG&E’s 2023 Wildfire Mitigation Plan, which is effective until the OEIS approves a new plan.

SDG&E submitted its request to the OEIS for its annual wildfire safety certification in September 2023. OEIS has until December 2023 to issue the certification or provide written notice explaining why additional time is needed. SDG&E’s existing certification remains valid until this pending request is resolved.

CAPITALIZED FINANCING COSTS

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

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


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra	$	128	$	65	$	311	$	182
SDG&E	28		30		90		84
SoCalGas	20		19		55		54

PROPERTY, PLANT AND EQUIPMENT

Sempra Infrastructure’s Sonora natural gas pipeline consists of two segments, the Sasabe-Puerto Libertad-Guaymas segment and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the pipeline in the Yaqui territory that has made that section inoperable since August 2017. Discussions with the CFE regarding the future of the pipeline are ongoing and the parties are working on restarting service on the pipeline, including the potential re-routing of a portion of the pipeline. If the parties do not agree on a definitive arrangement to re-route a portion of the pipeline or the parties do not agree on a new service start date, Sempra Infrastructure retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. At September 30, 2023, Sempra Infrastructure had $411 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline.

VARIABLE INTEREST ENTITIES

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

▪the purpose and design of the VIE;

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

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

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

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

SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at September 30, 2023 and December 31, 2022. PPAs and tolling agreements that relate to SDG&E’s involvement with VIEs are primarily accounted for as finance leases. The carrying amounts of the assets and liabilities under these contracts are included in PP&E, net, and finance lease liabilities with balances of $1,174 million and $1,194 million at September 30, 2023 and December 31, 2022, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Sempra Texas Utilities

Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $14,148 million and $13,665 million at September 30, 2023 and December 31, 2022, respectively.

Sempra Infrastructure

Cameron LNG JV

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, including LNG production and operation and maintenance activities at the liquefaction facility. Therefore, we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment, including amounts recognized in AOCI related to interest-rate cash flow hedges at Cameron LNG JV, was $989 million at September 30, 2023 and $886 million at December 31, 2022. Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and our obligation under the SDSRA, which we discuss in Note 5.

CFIN

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

ECA LNG Phase 1

ECA LNG Phase 1 is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that ECA LNG Phase 1 will require future capital contributions or other financial support to finance the construction of the facility. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $1,430 million and $1,099 million of assets at September 30, 2023 and December 31, 2022, respectively, consisting primarily of PP&E, net, attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $924 million and $685 million of liabilities at September 30, 2023 and December 31, 2022, respectively, consisting primarily of long-term debt, accounts payable and short-term debt attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 6, IEnova and TotalEnergies SE have provided guarantees for 83.4% and 16.6%, respectively, of the loan facility supporting construction of the liquefaction facility.

Port Arthur LNG

Port Arthur LNG is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that Port Arthur LNG will require future capital contributions or other financial support to finance the construction of the PA LNG Phase 1 project. Sempra is the primary beneficiary of this VIE because we have the power to direct the activities related to the construction and future operation and maintenance of the liquefaction facility. As a result, we consolidate Port Arthur LNG. Sempra consolidated $3,830 million of assets at September 30, 2023 consisting primarily of PP&E, net, other long-term assets and restricted cash 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 $788 million of liabilities at September 30, 2023 consisting primarily of accounts payable and long-term debt attributable to Port Arthur LNG for which creditors do not have recourse to the general credit of Sempra.

PENSION AND PBOP

Net Periodic Benefit Cost

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


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	25	$	27	$	3	$	4
Interest cost	39		29		9		7
Expected return on assets	(42)		(46)		(17)		(16)
Amortization of:
Prior service cost (credit)	2		3		(1)		(1)
Actuarial loss (gain)	3		8		(5)		(4)
Net periodic benefit cost (credit)	27		21		(11)		(10)
Regulatory adjustments	30		87		10		10
Total expense (income) recognized	$	57	$	108	$	(1)	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	82	$	110	$	10	$	17
Interest cost	118		88		28		21
Expected return on assets	(127)		(137)		(52)		(48)
Amortization of:
Prior service cost (credit)	4		8		(2)		(2)
Actuarial loss (gain)	7		19		(17)		(11)
Net periodic benefit cost (credit)	84		88		(33)		(23)
Regulatory adjustments	88		84		32		23
Total expense (income) recognized	$	172	$	172	$	(1)	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	8	$	8	$	1	$	1
Interest cost	10		7		2		1
Expected return on assets	(9)		(13)		(2)		(2)
Amortization of:
Actuarial loss (gain)	2		—		—		(1)
Net periodic benefit cost (credit)	11		2		1		(1)
Regulatory adjustments	3		24		(1)		1
Total expense recognized	$	14	$	26	$	—	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	24	$	28	$	2	$	4
Interest cost	30		20		6		4
Expected return on assets	(29)		(35)		(6)		(7)
Amortization of:
Actuarial loss (gain)	4		1		(1)		(2)
Net periodic benefit cost (credit)	29		14		1		(1)
Regulatory adjustments	11		26		(1)		1
Total expense recognized	$	40	$	40	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	15	$	16	$	2	$	3
Interest cost	24		20		7		5
Expected return on assets	(29)		(30)		(14)		(13)
Amortization of:
Prior service cost (credit)	1		2		(1)		(1)
Actuarial loss (gain)	1		6		(5)		(3)
Net periodic benefit cost (credit)	12		14		(11)		(9)
Regulatory adjustments	27		63		11		9
Total expense recognized	$	39	$	77	$	—	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	49	$	72	$	7	$	13
Interest cost	75		61		21		16
Expected return on assets	(89)		(94)		(44)		(40)
Amortization of:
Prior service cost (credit)	3		6		(2)		(2)
Actuarial loss (gain)	1		14		(15)		(9)
Net periodic benefit cost (credit)	39		59		(33)		(22)
Regulatory adjustments	77		58		33		22
Total expense recognized	$	116	$	117	$	—	$	—

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 $513 million and $505 million at September 30, 2023 and December 31, 2022, respectively.

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 September 30, 2023 and 2022
Sempra:
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
OCI before reclassifications	(5)		116		—		111
Amounts reclassified from AOCI(2)	—		(51)		1		(50)
Net OCI(2)	(5)		65		1		61
Balance at September 30, 2023	$	(43)	$	79	$	(96)	$	(60)

Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
OCI before reclassifications	—		40		—		40
Amounts reclassified from AOCI	—		5		2		7
Net OCI	—		45		2		47
Balance at September 30, 2022	$	(65)	$	15	$	(70)	$	(120)
SDG&E:




Balance at June 30, 2023 and September 30, 2023					$	(7)	$	(7)

Balance at June 30, 2022					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2022					$	(9)	$	(9)
SoCalGas:
Balance at June 30, 2023 and September 30, 2023			$	(11)	$	(11)	$	(22)






Balance at June 30, 2022			$	(12)	$	(17)	$	(29)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at September 30, 2022			$	(12)	$	(16)	$	(28)

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

(2) Total AOCI includes ($46) of financial instruments associated with sale of NCI to KKR Denali, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Nine months ended September 30, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	16		129		(13)		132
Amounts reclassified from AOCI(2)	—		(60)		3		(57)
Net OCI(2)	16		69		(10)		75
Balance at September 30, 2023	$	(43)	$	79	$	(96)	$	(60)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		151		7		162
Amounts reclassified from AOCI(3)	10		20		6		36
Net OCI(3)	14		171		13		198
Balance at September 30, 2022	$	(65)	$	15	$	(70)	$	(120)
SDG&E:




Balance at December 31, 2022 and September 30, 2023					$	(7)	$	(7)

Balance at December 31, 2021					$	(10)	$	(10)

Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2022					$	(9)	$	(9)
SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at September 30, 2023			$	(11)	$	(11)	$	(22)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		2		3
Net OCI			1		2		3
Balance at September 30, 2022			$	(12)	$	(16)	$	(28)

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

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


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended September 30,
	2023		2022
Sempra:


Financial instruments:
Interest rate instruments	$	1	$	2	Interest Expense
Interest rate instruments	(12)		1		Equity Earnings(1)

Foreign exchange instruments	(1)		—		Other Income (Expense), Net

Foreign exchange instruments	(1)		—		Equity Earnings
Interest rate and foreign exchange instruments	—		3		Other Income (Expense), Net
Total, before income tax	(13)		6
	2		(2)		Income Tax Benefit (Expense)
Total, net of income tax	(11)		4
	6		1		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(5)	$	5

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

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

Total reclassifications for the period, net of income tax and after NCI	$	(4)	$	7
SDG&E:
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income, Net


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



Pension and PBOP(2):

Amortization of prior service cost	$	—	$	1	Other Expense, Net






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

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

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


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

Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense
Interest rate instruments	(33)		28		Equity Earnings(1)
Foreign exchange instruments	—		(2)		Revenues: Energy-Related Businesses
	1		1		Other Income (Expense), Net
Foreign exchange instruments	1		(1)		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense
	(6)		(3)		Other Income (Expense), Net
Total, before income tax	(37)		23
	5		(7)		Income Tax Benefit (Expense)
Total, net of income tax	(32)		16
	18		4		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(14)	$	20

Pension and PBOP(2):
Amortization of actuarial loss	$	2	$	6	Other Income (Expense), Net
Amortization of prior service cost	2		3		Other Income (Expense), Net
Total, before income tax	4		9
	(1)		(3)		Income Tax Benefit (Expense)
Total, net of income tax	$	3	$	6

Total reclassifications for the period, net of income tax and after NCI	$	(11)	$	27
SDG&E:
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income, Net

Total reclassifications for the period, net of income tax	$	—	$	1
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense

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


Total, net of income tax	$	1	$	2

Total reclassifications for the period, net of income tax	$	2	$	3

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

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

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Common Stock

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

Sempra Common Stock 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.

All shares and per share information related to issued and outstanding common stock and outstanding equity awards with respect to common stock have been retroactively adjusted to reflect the stock split and are presented on a post-split basis herein.

Sempra Common Stock Repurchases

In the nine months ended September 30, 2023 and 2022, we repurchased 411,447 shares for $32 million and 404,806 shares for $28 million, respectively, of our common stock from long-term incentive plan participants to satisfy minimum statutory tax withholding requirements in connection with the vesting of RSUs and exercise of stock options.

On January 11, 2022, we entered into an ASR program under which we prepaid $200 million to repurchase shares of our common stock in a share forward transaction. A total of 2,945,512 shares were purchased under this program at an average price of $67.90 per share. The total number of shares purchased was determined by dividing the $200 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of January 12, 2022 through February 11, 2022, minus a fixed discount. The ASR program was completed on February 11, 2022.

On April 6, 2022, we entered into an ASR program under which we prepaid $250 million to repurchase shares of our common stock in a share forward transaction. A total of 2,943,914 shares were purchased under this program at an average price of $84.92 per share. The total number of shares purchased was determined by dividing the $250 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of April 7, 2022 through April 25, 2022, minus a fixed discount. The ASR program was completed on April 25, 2022.

Other Noncontrolling Interests

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


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	4,011	$	2,060
SI Partners subsidiaries(1)	0.1 - 42.0		0.1 - 16.6		989		61
Total Sempra					$	5,000	$	2,121

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

Sempra Infrastructure

Sale of NCI to KKR Denali. In September 2023, an indirect subsidiary of SI Partners completed the sale of an indirect 42% NCI in the PA LNG Phase 1 project to KKR Denali for aggregate cash consideration of approximately $984 million, including its pro rata equity share of development costs incurred prior to the closing that exceeded $439 million, subject to customary post-closing adjustments. As a result of this sale, we recorded a $1.1 billion increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $56 million, including $11 million in transaction costs and net of a $22 million tax benefit.

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

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

Sale of NCI to ConocoPhillips Affiliate. In March 2023, an indirect subsidiary of SI Partners completed the sale of an indirect 30% NCI in the PA LNG Phase 1 project to an affiliate of ConocoPhillips for aggregate cash consideration of $254 million, subject to customary post-closing adjustments. As a result of this sale, we recorded a $234 million increase in equity held by NCI and an increase in Sempra’s shareholders’ equity of $12 million, net of $3 million in transaction costs and $5 million in tax expense.

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

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

Sale of NCI to ADIA. In June 2022, Sempra and ADIA consummated the transaction contemplated under a purchase and sale agreement dated December 21, 2021 (the ADIA Purchase Agreement). Pursuant to the ADIA Purchase Agreement, ADIA acquired Class A Units representing a 10% NCI in SI Partners for a purchase price of $1.7 billion. Following the closing of the transaction, Sempra, KKR Pinnacle and ADIA directly or indirectly own 70%, 20%, and 10%, respectively, of the outstanding Class A Units of SI Partners, which excludes the non-voting Sole Risk Interests held only by Sempra. As a result of this sale to ADIA, we recorded a $709 million increase in equity held by NCI and an increase in Sempra’s shareholders’ equity of $710 million, net of $12 million in transaction costs and $300 million in tax impacts. Transaction costs include $10 million paid to ADIA for reimbursement of certain expenses that ADIA incurred in connection with closing the transaction.

Contributions from NCI. In October 2021, KKR Pinnacle acquired a 20% NCI in SI Partners. Under the limited partnership agreement that governs our and KKR Pinnacle’s respective rights and obligations in respect of our and their ownership interests in SI Partners, KKR Pinnacle was entitled to a $200 million credit from Sempra to be applied to capital calls once an LNG project reached a positive final investment decision and met certain projected internal rates of return. In the three months and nine months ended September 30, 2023, KKR Pinnacle used $14 million and $200 million, respectively, of this credit to fund its share of contributions to SI Partners. As a result, we recorded a $200 million increase in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $145 million, net of a tax benefit.

SEMPRA EARNINGS PER COMMON SHARE

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


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	721	$	485	$	2,293	$	1,656

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	630,036		629,447		629,963		630,603
Dilutive effect of stock options and RSUs(2)	2,288		2,728		2,268		2,311
Weighted-average common shares outstanding for diluted EPS	632,324		632,175		632,231		632,914

EPS:
Basic	$	1.14	$	0.77	$	3.64	$	2.63
Diluted	$	1.14	$	0.77	$	3.63	$	2.62

(1) Includes 716 and 803 fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2023 and 2022, respectively, and 716 and 805 of such RSUs for the nine months ended September 30, 2023 and 2022, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and nine months ended September 30, 2023 excludes 624,242 and 470,804 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and nine months ended September 30, 2022 excludes no potentially dilutive shares and 230,752 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

Pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Development Committee of Sempra’s board of directors granted 326,574 nonqualified stock options, 661,620 performance-based RSUs and 272,729 service-based RSUs in the nine months ended September 30, 2023, primarily in January.

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

TRANSACTIONS WITH AFFILIATES

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


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	September 30, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	34	$	41
Various affiliates	8		13
Total due from unconsolidated affiliates – current	$	42	$	54

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

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	—	$	(40)
5.5% Note due January 14, 2025	(24)		(23)
5.5% Note due July 16, 2025	(22)		(21)
5.5% Note due January 14, 2026	(20)		(19)
5.5% Note due July 14, 2026	(11)		(11)
5.5% Note due January 19, 2027	(14)		—
5.5% Note due July 21, 2027	(17)		—
TAG – 5.74% Note due December 17, 2029	(195)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(303)	$	(301)
SDG&E:
SoCalGas	$	8	$	—
Total due from unconsolidated affiliates – current	$	8	$	—

Sempra	$	(38)	$	(49)
SoCalGas	—		(72)
Various affiliates	(11)		(14)
Total due to unconsolidated affiliates – current	$	(49)	$	(135)

Income taxes due (to) from Sempra(2)	$	(43)	$	10
SoCalGas:
SDG&E	$	—	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	1	$	77

Sempra	$	(30)	$	(36)
SDG&E	(8)		—
Total due to unconsolidated affiliates – current	$	(38)	$	(36)

Income taxes due to Sempra(2)	$	(6)	$	(16)

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

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

The following table summarizes income statement information from unconsolidated affiliates.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra:
Revenues	$	10	$	10	$	34	$	32
Interest income	—		2		—		16
Interest expense	3		4		11		12
SDG&E:
Revenues	$	5	$	4	$	15	$	12
Cost of sales	25		17		82		67
SoCalGas:
Revenues	$	29	$	24	$	91	$	73
Cost of sales(1)	2		(1)		37		(5)

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

Guarantees

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

OTHER INCOME (EXPENSE), NET

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


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra:
Allowance for equity funds used during construction	$	35	$	35	$	105	$	104
Investment losses, net(1)	(19)		(13)		(2)		(60)
Gains (losses) on interest rate and foreign exchange instruments, net	1		(3)		5		2
Foreign currency transaction (losses) gains, net(2)	(3)		4		1		(18)
Non-service components of net periodic benefit cost	(28)		(77)		(79)		(45)
Interest on regulatory balancing accounts, net	19		7		56		12
Sundry, net	(2)		7		(11)		2
Total	$	3	$	(40)	$	75	$	(3)
SDG&E:
Allowance for equity funds used during construction	$	21	$	22	$	67	$	64
Non-service components of net periodic benefit cost	(5)		(17)		(14)		(8)
Interest on regulatory balancing accounts, net	10		5		31		9
Sundry, net	(1)		2		(9)		3
Total	$	25	$	12	$	75	$	68
SoCalGas:
Allowance for equity funds used during construction	$	14	$	14	$	38	$	40
Non-service components of net periodic benefit cost	(22)		(58)		(60)		(32)
Interest on regulatory balancing accounts, net	9		2		25		3
Sundry, net	(3)		(1)		(12)		(16)
Total	$	(2)	$	(43)	$	(9)	$	(5)

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

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

INCOME TAXES

We provide our calculations of ETRs in the following table.


INCOME TAX (BENEFIT) EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended September 30,						Nine months ended September 30,
	2023			2022			2023			2022
Sempra:
Income tax (benefit) expense	$	(52)		$	21		$	499		$	435

Income before income taxes and equity earnings	$	323		$	165		$	2,175		$	1,194
Equity earnings, before income tax(1)	133			134			418			436
Pretax income	$	456		$	299		$	2,593		$	1,630

Effective income tax rate	(11)		%	7		%	19		%	27		%
SDG&E:
Income tax (benefit) expense	$	(15)		$	35		$	(4)		$	141
Income before income taxes	$	259		$	306		$	712		$	822
Effective income tax rate	(6)		%	11		%	(1)		%	17		%
SoCalGas:
Income tax (benefit) expense	$	(5)		$	(28)		$	68		$	75
Income (loss) before income taxes	$	11		$	(110)		$	600		$	415
Effective income tax rate	(45)		%	25		%	11		%	18		%

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

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

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

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

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

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

▪utility self-developed software expenditures

▪depreciation on a certain portion of utility plant assets

▪state income taxes

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

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

In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the nine months ended September 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. SoCalGas recorded an associated regulatory liability for the portion that will benefit customers in the future. We are assessing the potential future impacts of this Revenue Procedure.In the nine months ended September 30, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested.

REGULATORY MATTERS (Tables)

9 Months Ended

Sep. 30, 2023

Regulated Operations [Abstract]

Schedule of Regulatory Assets


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

SDG&E:
Fixed-price contracts and other derivatives	$	(10)	$	(110)
Deferred income taxes recoverable in rates	518		296
Pension and PBOP plan obligations	(2)		11
Removal obligations	(2,382)		(2,248)
Environmental costs	105		107
Sunrise Powerlink fire mitigation	123		123
Regulatory balancing accounts(1)(2):
Commodity – electric	111		220
Gas transportation	15		60
Safety and reliability	186		107
Public purpose programs	(133)		(69)
Wildfire mitigation plan	607		375
Liability insurance premium	96		99
Other balancing accounts	(338)		(50)
Other regulatory assets, net(2)	96		137
Total SDG&E	(1,008)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	244		161
Pension and PBOP plan obligations	(265)		(170)
Employee benefit costs	24		24
Removal obligations	(597)		(616)
Environmental costs	39		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(356)		(257)
Safety and reliability	691		575
Public purpose programs	(149)		(158)
Liability insurance premium	23		23
Other balancing accounts	519		115
Other regulatory assets, net(2)	224		223
Total SoCalGas	397		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	3		—
Total Sempra Infrastructure	81		78
Total Sempra	$	(530)	$	(906)

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

Schedule of Regulatory Liabilities


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

SDG&E:
Fixed-price contracts and other derivatives	$	(10)	$	(110)
Deferred income taxes recoverable in rates	518		296
Pension and PBOP plan obligations	(2)		11
Removal obligations	(2,382)		(2,248)
Environmental costs	105		107
Sunrise Powerlink fire mitigation	123		123
Regulatory balancing accounts(1)(2):
Commodity – electric	111		220
Gas transportation	15		60
Safety and reliability	186		107
Public purpose programs	(133)		(69)
Wildfire mitigation plan	607		375
Liability insurance premium	96		99
Other balancing accounts	(338)		(50)
Other regulatory assets, net(2)	96		137
Total SDG&E	(1,008)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	244		161
Pension and PBOP plan obligations	(265)		(170)
Employee benefit costs	24		24
Removal obligations	(597)		(616)
Environmental costs	39		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(356)		(257)
Safety and reliability	691		575
Public purpose programs	(149)		(158)
Liability insurance premium	23		23
Other balancing accounts	519		115
Other regulatory assets, net(2)	224		223
Total SoCalGas	397		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	3		—
Total Sempra Infrastructure	81		78
Total Sempra	$	(530)	$	(906)

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

CPUC Authorized Cost of Capital and Rate Structure


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

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

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

The CCM was triggered for SDG&E and SoCalGas on September 30, 2023 and, subject to regulatory approval, would increase each of their authorized rates of return effective January 1, 2024 as follows:


PROPOSED CPUC 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	%

DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	1 Months Ended						9 Months Ended
DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	Aug. 31, 2023 USD ($)	Jun. 30, 2023 USD ($)	May 31, 2023 USD ($)	Mar. 31, 2023 USD ($)	Aug. 31, 2022 USD ($)	Jul. 31, 2022 USD ($)	Sep. 30, 2023 USD ($) bank lineOfCredit	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 9,900,000,000
Primary committed lines of credit \| lineOfCredit							7
Maximum ratio of indebtedness to total capitalization (as a percent)							65.00%
Uncommitted letters of credit outstanding							$ 508,000,000
Issuances of debt (maturities greater than 90 days)							6,911,000,000	$ 6,711,000,000
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity							200,000,000
Line of credit, amount outstanding							$ 37,000,000
Five Point Four Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 550,000,000
Stated rate of debt (as a percent)		5.40%
Proceeds from debt issuance		$ 545,000,000
Unamortized debt issuance costs and discounts		5,000,000
Five Point Five Zero Percent Senior Unsecured Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 700,000,000
Stated rate of debt (as a percent)		5.50%
Proceeds from debt issuance		$ 692,000,000
Unamortized debt issuance costs and discounts		$ 8,000,000
SI Partners
Line of Credit Facility [Line Items]
Maximum adjustment EBITDA allowed							5.25
SI Partners \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)				70.00%
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 200,000,000
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 200,000,000
Term of debt instrument (in years)				7 years
SI Partners and IEnova \| IEnova Uncommitted Line Of Credit Due 2024 \| Interbank Equilibrium Interest Rate
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)							1.05%
SI Partners and IEnova \| IEnova Uncommitted Line Of Credit Due 2024 \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)		1.15%
SI Partners and IEnova \| IEnova Uncommitted Line Of Credit Due 2024 \| London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)		1.05%
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 1,200,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)							65.00%
Issuances of debt (maturities greater than 90 days)							$ 997,000,000	1,497,000,000
Debt issuance costs							9,000,000	6,000,000
Southern California Gas Company \| Term Loan Due 2023
Line of Credit Facility [Line Items]
Issuances of debt (maturities greater than 90 days)					$ 800,000,000
Southern California Gas Company \| Term Loan Due 2023 \| Secured Debt
Line of Credit Facility [Line Items]
Term of debt instrument (in years)						364 days
Variable percentage rate (in percent)						0.70%
Debt amount						$ 800,000,000
Southern California Gas Company \| Term Loan Due 2023 \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount						$ 800,000,000
Southern California Gas Company \| Five Point Two Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.20%
Proceeds from debt issuance			$ 495,000,000
Unamortized debt issuance costs and discounts			5,000,000
Southern California Gas Company \| Five Point Seven Five Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount			$ 500,000,000
Stated rate of debt (as a percent)			5.75%
Proceeds from debt issuance			$ 493,000,000
Unamortized debt issuance costs and discounts			$ 7,000,000
Southern California Gas Company \| Senior Unsecured Floating Rate Notes \| Unsecured Debt
Line of Credit Facility [Line Items]
Debt amount		$ 300,000,000
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 1,500,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)							65.00%
Issuances of debt (maturities greater than 90 days)							$ 1,389,000,000	1,395,000,000
Debt issuance costs							$ 12,000,000	$ 9,000,000
San Diego Gas and Electric Company \| Five Point Three Five Zero Percent Senior Secured Notes \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount				$ 800,000,000
Stated rate of debt (as a percent)				5.35%
Proceeds from debt issuance				$ 783,000,000
Unamortized debt issuance costs and discounts				$ 17,000,000
San Diego Gas and Electric Company \| Four Point Nine Percent Green First Mortgage Bonds \| Secured Debt
Line of Credit Facility [Line Items]
Debt amount	$ 600,000,000
Stated rate of debt (as a percent)	4.95%
Proceeds from debt issuance	$ 593,000,000
Unamortized debt issuance costs and discounts	$ 7,000,000
Sempra LNG \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Term of debt instrument (in years)							5 years
Number of banks in syndicate \| bank							7
Weighted average interest rate (as a percent)							8.35%		7.54%
Sempra Infrastructure \| Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 1,300,000,000
Debt outstanding							$ 782,000,000		$ 575,000,000
IEnova \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							83.40%
Subsidiary of TOTAL SE \| ECA LNG JV
Line of Credit Facility [Line Items]
Ownership percentage in consolidated entity (in percentage)							16.60%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Term of debt instrument (in years)				20 years
Debt outstanding							$ 243,000,000
Weighted average interest rate (as a percent)							5.71%
Upfront equity funding amount				$ 4,700,000,000
Debt issuance costs				$ 200,000,000
Commitment fee (in percent)				30.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)				60.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, Before Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)				2.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Secured Overnight Financing Rate (SOFR) \| Interest Rate, After Completion of Phase 1
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)				2.25%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Minimum amount of the projected amount of term loans (in percent)				60.00%
Port Arthur LNG \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Domestic Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity							$ 6,800,000,000
SI Partners and ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project
Line of Credit Facility [Line Items]
Equity funding provided				$ 2,800,000,000
ConocoPhillips \| Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG
Line of Credit Facility [Line Items]
Ownership interest (as a percent)				30.00%

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,894	$ 3,106	$ 11,675	$ 9,828
Utilities regulatory revenues	197	357	76	685
Other revenues	243	154	1,478	471
Total revenues	3,334	3,617	13,229	10,984
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,541	2,587	10,815	8,589
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	353	519	860	1,239
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,506	1,738	7,750	6,010
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,388	1,368	3,925	3,818
Operating Segments \| San Diego Gas and Electric Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,438	1,383	4,603	4,134
Utilities regulatory revenues	4	186	(246)	279
Other revenues	0	0	0	0
Total revenues	1,442	1,569	4,357	4,413
Operating Segments \| San Diego Gas and Electric Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,438	1,383	4,603	4,134
Operating Segments \| San Diego Gas and Electric Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| San Diego Gas and Electric Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	182	175	988	664
Operating Segments \| San Diego Gas and Electric Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,256	1,208	3,615	3,470
Operating Segments \| Southern California Gas Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,120	1,214	6,252	4,473
Utilities regulatory revenues	193	171	322	406
Other revenues	0	0	0	0
Total revenues	1,313	1,385	6,574	4,879
Operating Segments \| Southern California Gas Company \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,120	1,214	6,252	4,473
Operating Segments \| Southern California Gas Company \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Southern California Gas Company \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,120	1,214	6,252	4,473
Operating Segments \| Southern California Gas Company \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments \| Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	387	551	983	1,348
Utilities regulatory revenues	0	0	0	0
Other revenues	242	146	1,502	462
Total revenues	629	697	2,485	1,810
Operating Segments \| Sempra Infrastructure \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	18	19	67	67
Operating Segments \| Sempra Infrastructure \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	369	532	916	1,281
Operating Segments \| Sempra Infrastructure \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	234	379	605	948
Operating Segments \| Sempra Infrastructure \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	153	172	378	400
Consolidation, Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(51)	(42)	(163)	(127)
Utilities regulatory revenues	0	0	0	0
Other revenues	1	8	(24)	9
Total revenues	(50)	(34)	(187)	(118)
Consolidation, Eliminations \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(35)	(29)	(107)	(85)
Consolidation, Eliminations \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(16)	(13)	(56)	(42)
Consolidation, Eliminations \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(30)	(30)	(95)	(75)
Consolidation, Eliminations \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (21)	$ (12)	$ (68)	$ (52)

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

Sep. 30, 2023

Dec. 31, 2022

Current assets:

Cash and cash equivalents

$ 1,149

$ 370

^[1]

Accounts receivable – trade, net

1,939

2,635

^[1]

Accounts receivable – other, net

498

685

^[1]

Due from unconsolidated affiliates

^[1]

Inventories

451

403

^[1]

Regulatory assets

190

351

^[1]

Greenhouse gas allowances

144

141

^[1]

Other current assets

^[1]

Total current assets

5,310

5,912

^[1]

Other assets:

Regulatory assets

3,277

2,588

^[1]

Greenhouse gas allowances

1,219

796

^[1]

Right-of-use assets – operating leases

721

655

^[1]

Other long-term assets

1,874

1,382

^[1]

Total other assets

27,253

24,880

^[1]

Property, plant and equipment:

Property, plant and equipment

70,348

63,893

^[1]

Less accumulated depreciation and amortization

(17,176)

(16,111)

^[1]

Property, plant and equipment, net

53,172

47,782

^[1]

Total assets

85,735

78,574

^[1]

Current liabilities:

Short-term debt

1,977

3,352

^[1]

Accounts payable – trade

2,234

1,994

^[1]

Accounts payable – other

219

275

^[1]

Accrued compensation and benefits

496

484

^[1]

Regulatory liabilities

529

504

^[1]

Current portion of long-term debt and finance leases

974

1,019

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

Greenhouse gas obligations

144

141

^[1]

Total current liabilities

8,765

9,899

^[1]

Long-term debt and finance leases

27,703

24,548

^[1]

Deferred credits and other liabilities:

Regulatory liabilities

3,468

3,341

^[1]

Greenhouse gas obligations

942

565

^[1]

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

309

410

^[1]

Deferred income taxes

5,095

4,591

^[1]

Asset retirement obligations

3,584

3,546

^[1]

Deferred credits and other

2,308

2,117

^[1]

Total deferred credits and other liabilities

16,009

14,871

^[1]

Commitments and contingencies

^[1]

Equity:

Common stock

12,038

12,160

^[1]

Retained earnings

15,371

14,201

^[1]

Accumulated other comprehensive income (loss)

(60)

(135)

^[1]

Total shareholders’ equity

28,238

27,115

^[1]

Total liabilities and equity

85,735

78,574

^[1]

Related Party

Current assets:

Due from unconsolidated affiliates

Current liabilities:

Other current liabilities

^[1]

Nonrelated Party

Current liabilities:

Other current liabilities

1,327

1,380

^[1]

Southern California Gas Company

Current assets:

Cash and cash equivalents

^[1]

Accounts receivable – trade, net

665

1,295

^[1]

Accounts receivable – other, net

293

^[1]

Due from unconsolidated affiliates

^[1]

Inventories

260

159

^[1]

Regulatory assets

172

104

^[1]

Greenhouse gas allowances

114

111

^[1]

Other current assets

^[1]

Total current assets

1,391

2,129

^[1]

Other assets:

Regulatory assets

1,505

1,291

^[1]

Greenhouse gas allowances

850

551

^[1]

Right-of-use assets – operating leases

^[1]

Other long-term assets

606

583

^[1]

Total other assets

2,993

2,467

^[1]

Property, plant and equipment:

Property, plant and equipment

26,401

25,058

^[1]

Less accumulated depreciation and amortization

(7,716)

(7,308)

^[1]

Property, plant and equipment, net

18,685

17,750

^[1]

Total assets

23,069

22,346

^[1]

Current liabilities:

Short-term debt

420

900

^[1]

Accounts payable – trade

570

953

^[1]

Accounts payable – other

177

176

^[1]

Accrued compensation and benefits

217

209

^[1]

Regulatory liabilities

229

394

^[1]

Current portion of long-term debt and finance leases

523

318

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

Greenhouse gas obligations

114

111

^[1]

Asset retirement obligations

^[1]

Total current liabilities

2,985

3,723

^[1]

Long-term debt and finance leases

6,291

5,780

^[1]

Deferred credits and other liabilities:

Regulatory liabilities

1,051

1,043

^[1]

Greenhouse gas obligations

748

443

^[1]

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

198

277

^[1]

Deferred income taxes

1,469

1,306

^[1]

Asset retirement obligations

2,726

2,675

^[1]

Deferred credits and other

370

401

^[1]

Total deferred credits and other liabilities

6,562

6,145

^[1]

Commitments and contingencies

^[1]

Equity:

Preferred stock

^[1]

Common stock

2,316

^[1]

Retained earnings

4,915

4,384

^[1]

Accumulated other comprehensive income (loss)

(22)

(24)

^[1]

Total shareholders’ equity

7,231

6,698

^[1]

Total liabilities and equity

23,069

22,346

^[1]

Southern California Gas Company | Related Party

Current assets:

Due from unconsolidated affiliates

Current liabilities:

Other current liabilities

^[1]

Southern California Gas Company | Nonrelated Party

Current liabilities:

Other current liabilities

$ 505

$ 429

^[1]

[1]	Derived from audited financial statements.

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

Sep. 30, 2023

Dec. 31, 2022

Due from unconsolidated affiliates

$ 42

$ 54

^[1]

Total due to unconsolidated affiliates – noncurrent

(303)

(301)

^[1]

Due from unconsolidated affiliates

Total due to unconsolidated affiliates – current

(5)

^[1]

Various affiliates

Due from unconsolidated affiliates

Tax Sharing Arrangement | Related Party

Due from unconsolidated affiliates

TAG Pipeline Norte | Related Party

Total due to unconsolidated affiliates – current

(5)

San Diego Gas and Electric Company

Due from unconsolidated affiliates

^[1]

San Diego Gas and Electric Company | Related Party

Due from unconsolidated affiliates

Total due to unconsolidated affiliates – current

(49)

(135)

^[1]

San Diego Gas and Electric Company | Various affiliates

Total due to unconsolidated affiliates – current

(11)

(14)

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

Total due to unconsolidated affiliates – current

(38)

(49)

Income taxes due (to) from Sempra

(43)

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

Due from unconsolidated affiliates

Total due to unconsolidated affiliates – current

(72)

Southern California Gas Company

Due from unconsolidated affiliates

^[1]

Southern California Gas Company | Related Party

Due from unconsolidated affiliates

Total due to unconsolidated affiliates – current

(38)

(36)

^[1]

Southern California Gas Company | Various affiliates

Due from unconsolidated affiliates

Southern California Gas Company | Due to/from Sempra Energy

Total due to unconsolidated affiliates – current

(30)

(36)

Income taxes due (to) from Sempra

(6)

(16)

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

Due from unconsolidated affiliates

Total due to unconsolidated affiliates – current

(8)

Sempra Infrastructure | Related Party

Total due to unconsolidated affiliates – noncurrent

$ (303)

(301)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ 0

(40)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (24)

(23)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (22)

(21)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (20)

(19)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (11)

(11)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (14)

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

Stated rate of debt (as a percent)

5.50%

Total due to unconsolidated affiliates – noncurrent

$ (17)

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

Stated rate of debt (as a percent)

5.74%

Total due to unconsolidated affiliates – noncurrent

$ (195)

$ (187)

[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Interest income	$ 2	$ 2	$ 5	$ 6
Total revenues from sales-type leases	2	2	5	6
Fixed lease payments	78	71	234	211
Variable lease payments	10	3	26	7
Total revenues from operating leases	88	74	260	218
Depreciation expense	$ 15	$ 14	$ 45	$ 41

REGULATORY MATTERS - GENERAL RATE CASE (Details) - 2024 GRC - 2024 Requirement - General Rate Case - USD ($) $ in Billions	1 Months Ended
	Oct. 31, 2023	May 31, 2022
San Diego Gas and Electric Company
General Rate Case [Line Items]
Requested revenue requirements		$ 3.0
San Diego Gas and Electric Company \| Subsequent Event
General Rate Case [Line Items]
Requested revenue requirements	$ 2.2
Requested review and recovery of wildfire mitigation plan	$ 1.5
San Diego Gas and Electric Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases		8.00%
San Diego Gas and Electric Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases		11.00%
Southern California Gas Company
General Rate Case [Line Items]
Requested revenue requirements		$ 4.4
Southern California Gas Company \| Minimum
General Rate Case [Line Items]
Estimate of annual increases		6.00%
Southern California Gas Company \| Maximum
General Rate Case [Line Items]
Estimate of annual increases		8.00%

CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,762	$ 1,877
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,651	1,500
Deferred income taxes and investment tax credits	234	387
Bad debt expense	368	110
Other	7	47
Reserve for Aliso Canyon costs	(3)	(1,835)
Net change in other working capital components	1,613	(267)
Insurance receivable for Aliso Canyon costs	0	350
Changes in other noncurrent assets and liabilities, net	(557)	(506)
Net cash provided by operating activities	5,129	1,455
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(6,074)	(3,540)
Net cash used in investing activities	(6,304)	(3,183)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(22)	(22)
Issuances of debt (maturities greater than 90 days)	6,911	6,711
Payments on debt (maturities greater than 90 days) and finance leases	(6,018)	(3,365)
Increase in short-term debt, net	629	(1,438)
Net cash provided by financing activities	2,198	1,936
Increase in cash, cash equivalents and restricted cash	1,029	205
Cash, cash equivalents and restricted cash, January 1	462	581
Cash, cash equivalents and restricted cash, September 30	1,491	786
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	836	732
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	1,200	738
Increase in finance lease obligations for investment in PP&E	47	33
(Decrease) increase in ARO for investment in PP&E	(15)	49
Southern California Gas Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	532	340
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	625	565
Deferred income taxes and investment tax credits	79	77
Bad debt expense	272	60
Other	(9)	(9)
Reserve for Aliso Canyon costs	(3)	(1,835)
Net change in other working capital components	2	98
Insurance receivable for Aliso Canyon costs	0	350
Changes in other noncurrent assets and liabilities, net	(234)	(408)
Net cash provided by operating activities	1,264	(762)
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,451)	(1,394)
Net cash used in investing activities	(1,451)	(1,394)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)	(1)
Equity contribution from Sempra	0	650
Issuances of debt (maturities greater than 90 days)	997	1,497
Payments on debt (maturities greater than 90 days) and finance leases	(1,115)	(10)
Increase in short-term debt, net	320	42
Debt issuance costs	(9)	(6)
Net cash provided by financing activities	192	2,172
Increase in cash, cash equivalents and restricted cash	5	16
Cash, cash equivalents and restricted cash, January 1	21	37
Cash, cash equivalents and restricted cash, September 30	26	53
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	183	123
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	253	235
Increase in finance lease obligations for investment in PP&E	40	21
(Decrease) increase in ARO for investment in PP&E	$ (28)	$ 48

COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

LEGAL PROCEEDINGS

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

At September 30, 2023, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $203 million for Sempra, including $127 million for SoCalGas. Amounts for Sempra and SoCalGas include $125 million for matters related to the Leak, which we discuss below.

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. This matter is subject to a motion for reconsideration, and subsequently an appeal if not otherwise resolved.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

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

Litigation. In September 2021, SoCalGas and Sempra entered into an agreement with counsel to resolve approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) 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 have not participated in the settlement (the Remaining Individual Plaintiffs) are able to continue to pursue their claims. In addition, as of October 31, 2023, new lawsuits related to the Leak on behalf of approximately 394 new plaintiffs have been filed against SoCalGas and Sempra since the September 2021 settlement.

The Remaining Individual Plaintiffs’ cases and new plaintiffs’ cases are coordinated before a single court in the LA 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. In October 2023, the LA Superior Court ordered the cases of 233 Remaining Individual Plaintiffs who did not respond to discovery requests to be dismissed.

Four shareholder derivative actions were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra and/or SoCalGas. Three of the four shareholder derivative actions were joined in an Amended Consolidated Shareholder Derivative Complaint filed in the same coordinated proceeding in the LA Superior Court, which was dismissed with prejudice in January 2021, and in June 2023, the Court of Appeal of the State of California Second Appellate District Division Five affirmed the dismissal. Plaintiffs have sought review in the California Supreme Court. The LA Superior Court dismissed the remaining fourth action with prejudice in November 2022. Plaintiffs appealed this dismissal, but in October 2023, abandoned the appeal; as a result, the dismissal is final.

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 November 2021, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting an interim range of gas inventory levels of up to 41.16 Bcf. In August 2023, the CPUC issued a decision approving a new interim range of gas inventory levels of up to 68.6 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final decision within the SB 380 OII proceeding.

At September 30, 2023, the Aliso Canyon natural gas storage facility had a net book value of $993 million. If the Aliso Canyon natural gas storage facility were to be permanently closed or if future cash flows from its operation were otherwise insufficient to recover its carrying value, we may record an impairment of the facility, which could be material, or we could incur materially higher than expected operating costs and/or be required to make material additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized.

Regulatory Proceeding – Resolved. In June 2019, the CPUC opened an OII (the Leak OII) to investigate and consider, among other things, whether SoCalGas should be sanctioned for the Leak and what damages, fines or other penalties, if any, should be imposed for any violations, unreasonable or imprudent practices or failure to cooperate sufficiently with SED, as well as to determine the amount of various costs incurred by SoCalGas and other parties in connection with the Leak and the ratemaking treatment or other disposition of such costs. In October 2022, SoCalGas executed a settlement agreement with SED and the Public Advocates Office at the CPUC to resolve all aspects of the Leak OII. The settlement agreement provides for financial penalties, certain costs that SoCalGas will reimburse, a violation of California Public Utilities Code section 451, and that SoCalGas will not seek recovery from ratepayers for costs previously incurred, among other provisions. In September 2023, the CPUC issued a final decision approving the settlement agreement.

Insurance and Accounting and Other Impacts. Since 2015, SoCalGas has incurred significant costs related to the Leak, including costs to defend against and settle civil litigation arising from the Leak. Other than insurance for directors’ and officers’ liability, we have exhausted all of our insurance for this matter. We continue to pursue other sources of insurance coverage for costs related to this matter, but we may not be successful in obtaining additional insurance recovery for any of these costs.

In the three months and nine months ended September 30, 2022, SoCalGas recorded total charges of $122 million ($101 million after tax) and $259 million ($199 million after tax), respectively, in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations related to the litigation and regulatory proceedings associated with the Leak.

At September 30, 2023, $126 million is accrued in Reserve for Aliso Canyon Costs and $3 million is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. These accruals do not include any amounts in excess of what has been estimated to resolve certain matters that we describe above in “Litigation” and “Regulatory Proceeding,” nor any amounts that may be necessary to resolve threatened litigation, other potential litigation or other costs, in each case to the extent it is not possible to predict at this time the outcome of these actions or reasonably estimate the possible costs or a range of possible costs. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued, which could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Sempra Infrastructure

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

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

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

▪In the first case, the court issued a provisional injunction 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 canceling the injunction but was not successful. The claimant’s underlying challenge to the permits remains pending.

▪In the second case, the initial request for a provisional injunction 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 claimants’ underlying challenge to the permits remains 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.

Litigation Related to Regulatory and Other Actions by the Mexican Government

Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective 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. However, a Mexican court issued a suspension of the amendments later in March 2021. In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law, but the qualified majority of eight votes out of 11 as is required in matters involving constitutionality was not reached and the proceeding was dismissed, which means that the Mexican Supreme Court did not issue a binding precedent and the amended Electricity Industry Law remains in force. Sempra Infrastructure filed three lawsuits against the amendments to the Electricity Industry Law and, in each of them, Sempra Infrastructure obtained a favorable judgment in the lower courts, which were challenged by the CRE. Final resolution is pending. If the proposed amendments are affirmed by the lower courts or by the Mexican Supreme Court (which in these cases would only require a simple majority vote), the CRE may be required to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, under a legal standard that is ambiguous and not well-defined under the law. If such self-supply permits granted under the former electricity law are revoked, it may result in increased costs for Sempra Infrastructure and 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.

Sonora Pipeline – Resolved

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

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

Other Litigation

RBS Sempra Commodities

Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against RBS (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE, a subsidiary of RBS Sempra Commodities. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a value-added tax liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million (approximately $55 million in U.S. dollars at September 30, 2023), plus costs and interest. In October 2020, the High Court of Justice assessed costs and interest to be approximately £21 million (approximately $26 million in U.S. dollars at September 30, 2023) as of that date, with interest continuing to accrue. The Defendants appealed and, in May 2021, the Court of Appeal set aside the High Court of Justice’s decision and ordered a retrial. In July 2022, the Supreme Court of the U.K. denied the Liquidating Companies application for permission to appeal the Court of Appeal’s decision. No date has been scheduled for the retrial. J.P. Morgan Chase & Co., which acquired RBS SEE and later sold it to Mercuria Energy Group, Ltd., previously notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and J.P. Morgan Chase & Co. has in turn sought indemnity from Sempra and RBS.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of October 31, 2023, two 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, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities.

SDG&E entered into an energy storage agreement that commenced in the second quarter of 2023 and expires in 2033. SDG&E recorded an operating lease right-of-use asset and operating lease liability of $101 million. Undiscounted lease payments are $9 million in 2023, $13 million in each of 2024 through 2027 and $66 million thereafter.

Leases That Have Not Yet Commenced

SDG&E has entered into seven purchased-power contracts, of which SDG&E expects one will commence in the fourth quarter of 2023, two 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 $32 million in 2024, $61 million in 2025, $82 million in 2026, $83 million in 2027 and $919 million thereafter until expiration in 2041.

Lessor Accounting

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

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


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

Interest income	$	2	$	2	$	5	$	6
Total revenues from sales-type leases(1)	$	2	$	2	$	5	$	6

Operating leases:
Fixed lease payments	$	78	$	71	$	234	$	211
Variable lease payments	10		3		26		7
Total revenues from operating leases(1)	$	88	$	74	$	260	$	218

Depreciation expense	$	15	$	14	$	45	$	41

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

CONTRACTUAL COMMITMENTS

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

Natural Gas Contracts

Sempra Infrastructure’s natural gas contracts and natural gas storage and transportation commitments have increased by approximately $877 million since December 31, 2022 primarily from entering into new storage and transportation contracts in the first nine months of 2023. We expect future payments to decrease by $29 million in 2023, and increase by $38 million in 2024, $35 million in 2025, $33 million in 2026, $30 million in 2027 and $770 million thereafter through expiration in 2059 compared to December 31, 2022.

LNG Purchase Agreement

Sempra Infrastructure has an SPA for the supply of LNG to the ECA Regas Facility. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2023 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At September 30, 2023, we expect the commitment amount to decrease by $980 million in 2023, $62 million in 2024, $45 million in 2025, $47 million in 2026, $58 million in 2027 and $136 million thereafter (through contract termination in 2029) compared to December 31, 2022, reflecting changes in estimated forward prices since December 31, 2022 and actual transactions for the first nine months of 2023. These LNG commitment amounts are based on the assumption that all LNG cargoes under the agreement are delivered, less those already confirmed to be diverted as of September 30, 2023. 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.

Purchased-Power Contracts

SDG&E’s purchased-power contract commitments have increased by approximately $482 million since December 31, 2022 primarily from entering into energy storage, hybrid renewable energy and energy storage, and resource adequacy agreements for the first nine months of 2023. At September 30, 2023, we expect the commitment amount to increase by $14 million in 2023, $3 million in 2024, $13 million in 2025, $32 million in 2026, $33 million in 2027, and $387 million thereafter through expiration in 2042 compared to December 31, 2022.

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 $53 million for Sempra, $19 million for SDG&E and $14 million for SoCalGas at September 30, 2023.

REVENUES

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

REVENUES

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


DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2023
By major service line:
Utilities	$	1,438	$	1,120	$	18	$	(35)	$	2,541
Energy-related businesses	—		—		369		(16)		353
Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894

By market:
Gas	$	182	$	1,120	$	234	$	(30)	$	1,506
Electric	1,256		—		153		(21)		1,388
Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894

Revenues from contracts with customers	$	1,438	$	1,120	$	387	$	(51)	$	2,894
Utilities regulatory revenues	4		193		—		—		197
Other revenues	—		—		242		1		243
Total revenues	$	1,442	$	1,313	$	629	$	(50)	$	3,334

	Nine months ended September 30, 2023
By major service line:
Utilities	$	4,603	$	6,252	$	67	$	(107)	$	10,815
Energy-related businesses	—		—		916		(56)		860
Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675

By market:
Gas	$	988	$	6,252	$	605	$	(95)	$	7,750
Electric	3,615		—		378		(68)		3,925
Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675

Revenues from contracts with customers	$	4,603	$	6,252	$	983	$	(163)	$	11,675
Utilities regulatory revenues	(246)		322		—		—		76
Other revenues	—		—		1,502		(24)		1,478
Total revenues	$	4,357	$	6,574	$	2,485	$	(187)	$	13,229


DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended September 30, 2022
By major service line:
Utilities	$	1,383	$	1,214	$	19	$	(29)	$	2,587
Energy-related businesses	—		—		532		(13)		519
Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106

By market:
Gas	$	175	$	1,214	$	379	$	(30)	$	1,738
Electric	1,208		—		172		(12)		1,368
Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106

Revenues from contracts with customers	$	1,383	$	1,214	$	551	$	(42)	$	3,106
Utilities regulatory revenues	186		171		—		—		357
Other revenues	—		—		146		8		154
Total revenues	$	1,569	$	1,385	$	697	$	(34)	$	3,617

	Nine months ended September 30, 2022
By major service line:
Utilities	$	4,134	$	4,473	$	67	$	(85)	$	8,589
Energy-related businesses	—		—		1,281		(42)		1,239
Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828

By market:
Gas	$	664	$	4,473	$	948	$	(75)	$	6,010
Electric	3,470		—		400		(52)		3,818
Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828

Revenues from contracts with customers	$	4,134	$	4,473	$	1,348	$	(127)	$	9,828
Utilities regulatory revenues	279		406		—		—		685
Other revenues	—		—		462		9		471
Total revenues	$	4,413	$	4,879	$	1,810	$	(118)	$	10,984

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2023 (excluding first nine months of 2023)	$	85	$	1
2024	300		4
2025	338		4
2026	365		4
2027	365		4
Thereafter	4,077		59
Total revenues to be recognized	$	5,530	$	76

(1) Excludes intercompany transactions.

Contract Liabilities from Revenues from Contracts with Customers


CONTRACT LIABILITIES
(Dollars in millions)
	2023		2022
Sempra:
Contract liabilities at January 1	$	(252)	$	(278)
Revenue from performance obligations satisfied during reporting period	9		129
Payments received in advance	(21)		(105)
Contract liabilities at September 30(1)	$	(264)	$	(254)
SDG&E:
Contract liabilities at January 1	$	(79)	$	(83)
Revenue from performance obligations satisfied during reporting period	3		3
Contract liabilities at September 30(2)	$	(76)	$	(80)

(1) Balances at September 30, 2023 include $9 in Other Current Liabilities and $255 in Deferred Credits and Other.

(2) Balances at September 30, 2023 include $4 in Other Current Liabilities and $72 in Deferred Credits and Other.

Receivables from Revenues from Contracts with Customers

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


RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	September 30, 2023		December 31, 2022
Sempra:
Accounts receivable – trade, net(1)	$	1,780	$	2,291
Accounts receivable – other, net	15		25
Due from unconsolidated affiliates – current(2)	5		9
Other long-term assets(3)	1		9
Total	$	1,801	$	2,334
SDG&E:
Accounts receivable – trade, net(1)	$	952	$	799
Accounts receivable – other, net	13		12
Due from unconsolidated affiliates – current(2)	6		2
Other long-term assets(3)	1		6
Total	$	972	$	819
SoCalGas:
Accounts receivable – trade, net	$	665	$	1,295
Accounts receivable – other, net	2		13
Other long-term assets(3)	—		3
Total	$	667	$	1,311

(1) At September 30, 2023 and December 31, 2022, includes $201 and $72, respectively, of receivables due from customers that were billed on behalf of CCAs, which are not included in revenues.

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

- Definition

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.

+ References

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

+ Details

REGULATORY MATTERS

9 Months Ended

Sep. 30, 2023

Regulated Operations [Abstract]

REGULATORY MATTERS


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

SDG&E:
Fixed-price contracts and other derivatives	$	(10)	$	(110)
Deferred income taxes recoverable in rates	518		296
Pension and PBOP plan obligations	(2)		11
Removal obligations	(2,382)		(2,248)
Environmental costs	105		107
Sunrise Powerlink fire mitigation	123		123
Regulatory balancing accounts(1)(2):
Commodity – electric	111		220
Gas transportation	15		60
Safety and reliability	186		107
Public purpose programs	(133)		(69)
Wildfire mitigation plan	607		375
Liability insurance premium	96		99
Other balancing accounts	(338)		(50)
Other regulatory assets, net(2)	96		137
Total SDG&E	(1,008)		(942)
SoCalGas:
Deferred income taxes recoverable in rates	244		161
Pension and PBOP plan obligations	(265)		(170)
Employee benefit costs	24		24
Removal obligations	(597)		(616)
Environmental costs	39		38
Regulatory balancing accounts(1)(2):
Commodity – gas, including transportation	(356)		(257)
Safety and reliability	691		575
Public purpose programs	(149)		(158)
Liability insurance premium	23		23
Other balancing accounts	519		115
Other regulatory assets, net(2)	224		223
Total SoCalGas	397		(42)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	78		78
Other regulatory assets	3		—
Total Sempra Infrastructure	81		78
Total Sempra	$	(530)	$	(906)

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

SEMPRA CALIFORNIA

CPUC GRC

CPUC Cost of Capital


CPUC AUTHORIZED COST OF CAPITAL FOR 2023 – 2025

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

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

The CCM was triggered for SDG&E and SoCalGas on September 30, 2023 and, subject to regulatory approval, would increase each of their authorized rates of return effective January 1, 2024 as follows:


PROPOSED CPUC 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	%

SDG&E

FERC Rate Matters

SAN ONOFRE NUCLEAR GENERATING STATION

NUCLEAR DECOMMISSIONING AND FUNDING


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	September 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	44	$	1	$	(2)	$	43
Municipal bonds(2)	278		—		(18)		260
Other securities(3)	234		1		(19)		216
Total debt securities	556		2		(39)		519
Equity securities	99		201		(5)		295
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(11)		—		—		(11)
Total	$	668	$	203	$	(44)	$	827

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

(1) Maturity dates are 2023-2054.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Proceeds from sales	$	143	$	133	$	437	$	530
Gross realized gains	12		2		20		16
Gross realized losses	(3)		(3)		(9)		(14)

ASSET RETIREMENT OBLIGATION

CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Operating expenses:
Aliso Canyon litigation and regulatory matters	$ 0	$ 122	$ 0	$ 259
Other income (expense), net	3	(40)	75	(3)
Interest income	19	18	60	58
Interest expense	(312)	(282)	(995)	(796)
Income before income taxes and equity earnings	323	165	2,175	1,194
Income tax benefit (expense)	52	(21)	(499)	(435)
Net income	854	561	2,762	1,877
Preferred dividends	(11)	(11)	(33)	(33)
Earnings attributable to common shares	721	485	2,293	1,656
Southern California Gas Company
REVENUES
Operating revenues	1,313	1,385	6,574	4,879
Operating expenses:
Cost of natural gas	224	441	2,855	1,577
Operation and maintenance	733	590	2,073	1,746
Aliso Canyon litigation and regulatory matters	0	122	0	259
Depreciation and amortization	211	190	625	565
Franchise fees and other taxes	64	62	209	181
Total operating expenses	1,232	1,405	5,762	4,328
Operating income (loss)	81	(20)	812	551
Other income (expense), net	(2)	(43)	(9)	(5)
Interest income	2	3	7	4
Interest expense	(70)	(50)	(210)	(135)
Income before income taxes and equity earnings	11	(110)	600	415
Income tax benefit (expense)	5	28	(68)	(75)
Net income	16	(82)	532	340
Preferred dividends	0	0	(1)	(1)
Earnings attributable to common shares	$ 16	$ (82)	$ 531	$ 339

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Dividends declared per share of common stock (in dollars per share)	$ 0.60	$ 0.57	$ 1.79	$ 1.72
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19	$ 36.57	$ 36.57

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 128	$ 65	$ 311	$ 182
San Diego Gas and Electric Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	28	30	90	84
Southern California Gas Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 20	$ 19	$ 55	$ 54

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

9 Months Ended

Sep. 30, 2023

Public Utilities, General Disclosures [Abstract]

Schedule of Nuclear Decommissioning Trusts Investments


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	September 30, 2023
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	44	$	1	$	(2)	$	43
Municipal bonds(2)	278		—		(18)		260
Other securities(3)	234		1		(19)		216
Total debt securities	556		2		(39)		519
Equity securities	99		201		(5)		295
Short-term investments, primarily cash equivalents	24		—		—		24
Receivables (payables), net	(11)		—		—		(11)
Total	$	668	$	203	$	(44)	$	827

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

(1) Maturity dates are 2023-2054.

(2) Maturity dates are 2023-2062.

(3) Maturity dates are 2023-2072.

Schedule of Sales of Securities By Nuclear Decommissioning Trusts

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


SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Proceeds from sales	$	143	$	133	$	437	$	530
Gross realized gains	12		2		20		16
Gross realized losses	(3)		(3)		(9)		(14)

- Definition

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

+ References

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

+ Details

DEBT AND CREDIT FACILITIES (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities


COMMITTED LINES OF CREDIT
(Dollars in millions)
		September 30, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Letters of credit outstanding		Available unused credit
Sempra	October 2028(1)	$	4,000	$	(970)	$	—	$	—	$	3,030
SDG&E	October 2028(1)	1,500		—		—		—		1,500
SoCalGas	October 2028(1)	1,200		(421)		—		—		779
SI Partners and IEnova	September 2025(2)	500		—		(350)		—		150
SI Partners and IEnova	August 2026(3)	1,000		—		—		—		1,000
SI Partners and IEnova	August 2028(4)	1,500		—		(201)		—		1,299
Port Arthur LNG	March 2030	200		—		—		(25)		175
Total		$	9,900	$	(1,391)	$	(551)	$	(25)	$	7,933

(1) In October 2023, Sempra, SDG&E and SoCalGas each amended their respective credit facility to extend the expiration date from October 2027 to October 2028. Each credit facility will maintain a syndicate of 23 lenders through October 2027, at which time the syndicate of lenders for each credit facility will be reduced to 22 unless a new or existing lender agrees to assume the 23rd lender’s commitment. Such a reduction in lenders would result in a reduction to the available credit capacity to $3,845, $1,442 and $1,153 for Sempra, SDG&E and SoCalGas, respectively, through October 2028.

(2) In September 2023, the $150 facility was terminated and the $350 facility was amended to increase the commitment to $500, adjust the applicable margin to 80 bps (including credit adjustment spread), and extend the expiration date from September 2023 to September 2025.

(3) In August 2023, the facility was amended to include IEnova as a co-borrower, adjust the Term SOFR credit adjustment spread to 10 bps in all tenors, and extend the expiration date from November 2024 to August 2026. Additionally, either SI Partners or IEnova has the right to increase the total facility to $1,500, subject to lender approval.

(4) In August 2023, the facility was amended to extend the expiration date from February 2024 to August 2028.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		September 30, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2024 - May 2024	$	15
SoCalGas	March 2024 - November 2024	20
Sempra Infrastructure	October 2023 - October 2043	307
Parent and other	March 2024 - September 2024	166
Total		$	508

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


WEIGHTED-AVERAGE INTEREST RATES

	September 30, 2023		December 31, 2022
Sempra	5.86	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.37		4.71

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Mar. 31, 2022
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 1,801		$ 2,334
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	181	$ 136
Provisions for expected credit losses	374	111
Write-offs	(74)	(57)
Ending balance	481	190
Allowance for credit losses	6		7
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	432		140
Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	15		25
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	48		40
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	1		9
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	1		1
Other long-term assets \| KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	6		7
Deferred Credits and Other \| Sempra LNG
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses	6		6
San Diego Gas and Electric Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	972		819
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	78	66
Provisions for expected credit losses	96	51
Write-offs	(34)	(30)
Ending balance	140	87
San Diego Gas and Electric Company \| Customers Under California Arrearage Payment Program
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			51	$ 63
San Diego Gas and Electric Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	113		52
San Diego Gas and Electric Company \| Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	13		12
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	26		25
San Diego Gas and Electric Company \| Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	1		6
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	1		1
Southern California Gas Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	667		1,311
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	98	69
Provisions for expected credit losses	276	58
Write-offs	(40)	(27)
Ending balance	334	$ 100
Southern California Gas Company \| Customers Under California Arrearage Payment Program
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			59	$ 79
Southern California Gas Company \| Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	312		83
Southern California Gas Company \| Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	2		13
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	22		15
Southern California Gas Company \| Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 0		$ 3

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

3 Months Ended

9 Months Ended

Sep. 30, 2023

Sep. 30, 2022

Sep. 30, 2023

Sep. 30, 2022

Dec. 31, 2022

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

$ 3,334

$ 3,617

$ 13,229

$ 10,984

DEPRECIATION AND AMORTIZATION

563

506

1,651

1,500

INTEREST INCOME

INTEREST EXPENSE

312

282

995

796

INCOME TAX (BENEFIT) EXPENSE

(52)

499

435

Equity earnings, before income tax:

133

134

418

436

Equity earnings, net of income tax:

346

283

668

682

Equity earnings

479

417

1,086

1,118

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

721

485

2,293

1,656

Segment Reporting Information, Additional Information [Abstract]

EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT

6,074

3,540

ASSETS

85,735

$ 78,574

^[1]

EQUITY METHOD INVESTMENTS

16,356

15,677

Operating Segments | SDG&E

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

1,442

1,569

4,357

4,413

DEPRECIATION AND AMORTIZATION

280

247

810

730

INTEREST INCOME

INTEREST EXPENSE

126

113

367

333

INCOME TAX (BENEFIT) EXPENSE

(15)

(4)

141

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

274

271

716

681

Segment Reporting Information, Additional Information [Abstract]

EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT

1,893

1,651

ASSETS

28,502

26,422

Operating Segments | SoCalGas

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

1,313

1,385

6,574

4,879

DEPRECIATION AND AMORTIZATION

211

190

625

565

INTEREST INCOME

INTEREST EXPENSE

210

135

INCOME TAX (BENEFIT) EXPENSE

(5)

(28)

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

(82)

531

339

Segment Reporting Information, Additional Information [Abstract]

EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT

1,451

1,394

ASSETS

23,069

22,346

Operating Segments | Sempra Texas Utilities

Segment Reporting Information, Profit (Loss) [Abstract]

INCOME TAX (BENEFIT) EXPENSE

Equity earnings, before income tax:

Equity earnings, net of income tax:

305

257

548

603

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

305

256

548

604

Segment Reporting Information, Additional Information [Abstract]

ASSETS

14,269

13,781

EQUITY METHOD INVESTMENTS

14,260

13,772

Operating Segments | Sempra Infrastructure

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

629

697

2,485

1,810

DEPRECIATION AND AMORTIZATION

210

199

INTEREST INCOME

INTEREST EXPENSE

127

INCOME TAX (BENEFIT) EXPENSE

555

219

Equity earnings, before income tax:

131

133

413

430

Equity earnings, net of income tax:

120

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

223

114

746

392

Segment Reporting Information, Additional Information [Abstract]

EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT

2,725

489

ASSETS

19,722

15,760

EQUITY METHOD INVESTMENTS

2,096

1,905

All other

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

DEPRECIATION AND AMORTIZATION

INTEREST INCOME

INTEREST EXPENSE

109

292

232

INCOME TAX (BENEFIT) EXPENSE

(56)

(45)

(120)

(1)

EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES

(97)

(74)

(248)

(360)

Segment Reporting Information, Additional Information [Abstract]

EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT

ASSETS

1,205

1,376

Adjustments and eliminations

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

(1)

Intersegment revenues and eliminations

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

(50)

(35)

(186)

(119)

INTEREST INCOME

(1)

INTEREST EXPENSE

(1)

(2)

Segment Reporting Information, Additional Information [Abstract]

ASSETS

(1,032)

$ (1,111)

Intersegment revenues and eliminations | SDG&E

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

(5)

(4)

(14)

(11)

Intersegment revenues and eliminations | SoCalGas

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

(29)

(24)

(91)

(73)

Intersegment revenues and eliminations | Sempra Infrastructure

Segment Reporting Information, Profit (Loss) [Abstract]

REVENUES

$ (16)

$ (7)

$ (81)

$ (35)

[1]	Derived from audited financial statements.

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Interest rate and foreign exchange instruments
Derivative [Line Items]
Notional amount of derivative	$ 0	$ 306
Foreign exchange instruments
Derivative [Line Items]
Notional amount of derivative	150	111
Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Notional amount of derivative	4,454	294
Cash Flow Hedging \| Interest Rate Swap
Derivative [Line Items]
Notional amounts	$ 491	$ 294

- Definition

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

+ References + Details

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

Sep. 30, 2023

Dec. 31, 2022

Inventory [Line Items]

Natural gas

$ 160

$ 106

LNG

Materials and supplies

282

235

Total

451

403

^[1]

San Diego Gas and Electric Company

Inventory [Line Items]

Natural gas

LNG

Materials and supplies

146

133

Total

147

134

^[1]

Southern California Gas Company

Inventory [Line Items]

Natural gas

144

LNG

Materials and supplies

116

Total

$ 260

$ 159

^[1]

[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
REVENUES
Natural gas	$ 1,488	$ 1,587	$ 7,560	$ 5,611
Electric	1,250	1,357	3,331	3,663
Energy-related businesses	596	673	2,338	1,710
Total revenues	3,334	3,617	13,229	10,984
Operating expenses:
Operation and maintenance	(1,383)	(1,206)	(3,958)	(3,454)
Aliso Canyon litigation and regulatory matters	0	(122)	0	(259)
Depreciation and amortization	(563)	(506)	(1,651)	(1,500)
Franchise fees and other taxes	(169)	(162)	(509)	(474)
Other income (expense), net	3	(40)	75	(3)
Interest income	19	18	60	58
Interest expense	(312)	(282)	(995)	(796)
Income before income taxes and equity earnings	323	165	2,175	1,194
Income tax benefit (expense)	52	(21)	(499)	(435)
Equity earnings	479	417	1,086	1,118
Net income	854	561	2,762	1,877
Earnings attributable to noncontrolling interests	(122)	(65)	(435)	(187)
Preferred dividends	(11)	(11)	(33)	(33)
Preferred dividends of subsidiary	0	0	(1)	(1)
Earnings attributable to common shares	$ 721	$ 485	$ 2,293	$ 1,656
Basic EPS:
Earnings (in dollars per share)	$ 1.14	$ 0.77	$ 3.64	$ 2.63
Weighted-average common shares outstanding (in shares)	630,036	629,447	629,963	630,603
Diluted EPS:
Earnings (in dollars per share)	$ 1.14	$ 0.77	$ 3.63	$ 2.62
Weighted-average common shares outstanding (in shares)	632,324	632,175	632,231	632,914
Natural gas
Operating expenses:
Operating expenses	$ (260)	$ (505)	$ (3,254)	$ (1,835)
Electric fuel and purchased power
Operating expenses:
Operating expenses	(183)	(307)	(385)	(763)
Energy-related businesses
Operating expenses:
Operating expenses	$ (163)	$ (340)	$ (437)	$ (764)

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 838	$ 845
Short-term investments held in Rabbi Trust	62	55
Support Agreement, net of related guarantee fees	18	17
Total	1,498	1,871
Total	178	374
Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	295	297
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	43	40
Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270
Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	216	227
Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	519	537
Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	378	76
Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12	273
Effect of netting and allocation of collateral	89	451
Derivative liabilities	13	191
Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18	136
Effect of netting and allocation of collateral	82	18
Derivative liabilities	158	70
Effect of netting and allocation of collateral	(1)
Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Derivative liabilities	8	8
Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		105
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	339	330
Short-term investments held in Rabbi Trust	62	55
Support Agreement, net of related guarantee fees	0	0
Total	566	930
Total	1	0
Level 1 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	21	10
Level 1 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	291	293
Level 1 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	27	27
Level 1 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 1 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 1 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	27	27
Level 1 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Level 1 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	89	451
Derivative liabilities	0	0
Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	82
Effect of netting and allocation of collateral	76	12
Derivative liabilities	2	0
Effect of netting and allocation of collateral	(1)
Level 1 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liabilities	0	0
Level 1 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	499	515
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	890	883
Total	177	374
Level 2 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	3	1
Level 2 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	4	4
Level 2 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	16	13
Level 2 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270
Level 2 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	216	227
Level 2 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	492	510
Level 2 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	378	76
Level 2 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12	273
Effect of netting and allocation of collateral	0	0
Derivative liabilities	13	191
Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	19
Effect of netting and allocation of collateral	0	0
Derivative liabilities	156	70
Effect of netting and allocation of collateral	0
Level 2 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Derivative liabilities	8	8
Level 2 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		105
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	18	17
Total	42	58
Total	0	0
Level 3 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Level 3 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	0
Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18	35
Effect of netting and allocation of collateral	6	6
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0
Level 3 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liabilities	0	0
Level 3 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
San Diego Gas and Electric Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	838	845
Total	936	982
Total	1	1
San Diego Gas and Electric Company \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
San Diego Gas and Electric Company \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	295	297
San Diego Gas and Electric Company \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	43	40
San Diego Gas and Electric Company \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270
San Diego Gas and Electric Company \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	216	227
San Diego Gas and Electric Company \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	519	537
San Diego Gas and Electric Company \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18	120
Effect of netting and allocation of collateral	80	17
Derivative liabilities	2	1
Effect of netting and allocation of collateral	(1)
San Diego Gas and Electric Company \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	339	330
Total	413	423
Total	1	0
San Diego Gas and Electric Company \| Level 1 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	21	10
San Diego Gas and Electric Company \| Level 1 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	291	293
San Diego Gas and Electric Company \| Level 1 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	27	27
San Diego Gas and Electric Company \| Level 1 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 1 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 1 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	27	27
San Diego Gas and Electric Company \| Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	82
Effect of netting and allocation of collateral	74	11
Derivative liabilities	2	0
Effect of netting and allocation of collateral	(1)
San Diego Gas and Electric Company \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	499	515
Total	499	518
Total	0	1
San Diego Gas and Electric Company \| Level 2 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	3	1
San Diego Gas and Electric Company \| Level 2 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	4	4
San Diego Gas and Electric Company \| Level 2 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	16	13
San Diego Gas and Electric Company \| Level 2 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270
San Diego Gas and Electric Company \| Level 2 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	216	227
San Diego Gas and Electric Company \| Level 2 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	492	510
San Diego Gas and Electric Company \| Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	3
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	1
Effect of netting and allocation of collateral	0
San Diego Gas and Electric Company \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Total	24	41
Total	0	0
San Diego Gas and Electric Company \| Level 3 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company \| Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18	35
Effect of netting and allocation of collateral	6	6
Derivative liabilities	0	0
Effect of netting and allocation of collateral	0
Southern California Gas Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	2	17
Total	156	69
Southern California Gas Company \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		16
Effect of netting and allocation of collateral	2	1
Derivative liabilities	156	69
Southern California Gas Company \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	2	1
Total	0	0
Southern California Gas Company \| Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		0
Effect of netting and allocation of collateral	2	1
Derivative liabilities	0	0
Southern California Gas Company \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	16
Total	156	69
Southern California Gas Company \| Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		16
Effect of netting and allocation of collateral	0	0
Derivative liabilities	156	69
Southern California Gas Company \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	0
Total	0	0
Southern California Gas Company \| Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	$ 0	$ 0

FAIR VALUE MEASUREMENTS (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	21	$	3	$	—	$	24
Equity securities	291		4		—		295
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		16		—		43
Municipal bonds	—		260		—		260
Other securities	—		216		—		216
Total debt securities	27		492		—		519
Total nuclear decommissioning trusts(1)	339		499		—		838
Short-term investments held in Rabbi Trust	62		—		—		62
Interest rate instruments	—		378		—		378
Foreign exchange instruments	—		1		—		1
Commodity contracts not subject to rate recovery	—		12		—		12
Effect of netting and allocation of collateral(2)	89		—		—		89
Commodity contracts subject to rate recovery	—		—		18		18
Effect of netting and allocation of collateral(2)	76		—		6		82
Support Agreement, net of related guarantee fees	—		—		18		18
Total	$	566	$	890	$	42	$	1,498
Liabilities:
Foreign exchange instruments	$	—	$	8	$	—	$	8
Commodity contracts not subject to rate recovery	—		13		—		13
Commodity contracts subject to rate recovery	2		156		—		158
Effect of netting and allocation of collateral(2)	(1)		—		—		(1)
Total	$	1	$	177	$	—	$	178

(1) Excludes receivables (payables), net.

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


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

1) Excludes receivables (payables), net.

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


RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	21	$	3	$	—	$	24
Equity securities	291		4		—		295
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	27		16		—		43
Municipal bonds	—		260		—		260
Other securities	—		216		—		216
Total debt securities	27		492		—		519
Total nuclear decommissioning trusts(1)	339		499		—		838
Commodity contracts subject to rate recovery	—		—		18		18
Effect of netting and allocation of collateral(2)	74		—		6		80
Total	$	413	$	499	$	24	$	936
Liabilities:
Commodity contracts subject to rate recovery	$	2	$	—	$	—	$	2
Effect of netting and allocation of collateral(2)	(1)		—		—		(1)
Total	$	1	$	—	$	—	$	1

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

(1) Excludes receivables (payables), net.

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


RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
	Level 1		Level 2		Level 3		Total
	Fair value at September 30, 2023
Assets:
Effect of netting and allocation of collateral(1)	$	2	$	—	$	—	$	2
Total	$	2	$	—	$	—	$	2
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	156	$	—	$	156
Total	$	—	$	156	$	—	$	156

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

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

Recurring Fair Value Measures Level 3 Rollforward


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended September 30,
	2023		2022
Balance at July 1	$	20	$	33
Realized and unrealized losses	(2)		(35)
Allocated transmission instruments	1		2
Settlements	(1)		33
Balance at September 30	$	18	$	33
Change in unrealized gains relating to instruments still held at September 30	$	1	$	3

	Nine months ended September 30,
	2023		2022
Balance at January 1	$	35	$	54
Realized and unrealized losses	(10)		(58)
Allocated transmission instruments	(1)		(4)
Settlements	(6)		41
Balance at September 30	$	18	$	33
Change in unrealized losses relating to instruments still held at September 30	$	(8)	$	(15)

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

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


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended September 30,
	2023		2022
Balance at July 1	$	23	$	16
Realized and unrealized (losses) gains(1)	(3)		2
Settlements	(2)		(2)
Balance at September 30(2)	$	18	$	16
Change in unrealized (losses) gains relating to instruments still held at September 30	$	(2)	$	2

	Nine months ended September 30,
	2023		2022
Balance at January 1	$	17	$	7
Realized and unrealized gains(1)	7		16
Settlements	(6)		(7)
Balance at September 30(2)	$	18	$	16
Change in unrealized gains relating to instruments still held at September 30	$	7	$	15

(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 $11 in Other Long-term Assets at September 30, 2023 on Sempra’s Condensed Consolidated Balance Sheet.

Schedule of Fair Value Inputs

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


CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS

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

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
	September 30, 2023
Sempra:

Long-term note receivable(1)	$	330	$	—	$	—	$	295	$	295
Long-term amounts due to unconsolidated affiliates	308		—		269		—		269
Total long-term debt(2)	27,657		—		23,765		—		23,765
SDG&E:
Total long-term debt(3)	$	8,750	$	—	$	7,202	$	—	$	7,202
SoCalGas:
Total long-term debt(4)	$	6,759	$	—	$	5,953	$	—	$	5,953

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

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Southern California Gas Company
Dividends declared per share of preferred stock (in dollars per share)	$ 0.38	$ 0.38	$ 1.13	$ 1.13

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER INCOME, NET (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Other Income [Line Items]
Allowance for equity funds used during construction	$ 35	$ 35	$ 105	$ 104
Investment gains (losses), net	(19)	(13)	(2)	(60)
Gains (losses) on interest rate and foreign exchange instruments, net	1	(3)	5	2
Foreign currency transaction gains (losses), net	(3)	4	1	(18)
Non-service components of net periodic benefit cost	(28)	(77)	(79)	(45)
Interest on regulatory balancing accounts, net	19	7	56	12
Sundry, net	(2)	7	(11)	2
Total	3	(40)	75	(3)
San Diego Gas and Electric Company
Other Income [Line Items]
Allowance for equity funds used during construction	21	22	67	64
Non-service components of net periodic benefit cost	(5)	(17)	(14)	(8)
Interest on regulatory balancing accounts, net	10	5	31	9
Sundry, net	(1)	2	(9)	3
Total	25	12	75	68
Southern California Gas Company
Other Income [Line Items]
Allowance for equity funds used during construction	14	14	38	40
Non-service components of net periodic benefit cost	(22)	(58)	(60)	(32)
Interest on regulatory balancing accounts, net	9	2	25	3
Sundry, net	(3)	(1)	(12)	(16)
Total	$ (2)	$ (43)	$ (9)	(5)
IMG
Other Income [Line Items]
Foreign currency transaction gains (losses), net				$ 11

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Cost	$ 668		$ 668		$ 689
Gross unrealized gains	203		203		196
Gross unrealized losses	(44)		(44)		(44)
Estimated fair value	827		827		841
Proceeds from sales	143	$ 133	437	$ 530
Gross realized gains	12	2	20	16
Gross realized losses	(3)	$ (3)	(9)	$ (14)
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	556		556		571
Gross unrealized gains	2		2		2
Gross unrealized losses	(39)		(39)		(36)
Estimated fair value	519		519		537
U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	44		44		40
Gross unrealized gains	1		1		1
Gross unrealized losses	(2)		(2)		(1)
Estimated fair value	43		43		40
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	278		278		283
Gross unrealized gains	0		0		1
Gross unrealized losses	(18)		(18)		(14)
Estimated fair value	260		260		270
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	234		234		248
Gross unrealized gains	1		1		0
Gross unrealized losses	(19)		(19)		(21)
Estimated fair value	216		216		227
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	99		99		111
Gross unrealized gains	201		201		194
Gross unrealized losses	(5)		(5)		(8)
Estimated fair value	295		295		297
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	24		24		11
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	24		24		11
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(11)		(11)		(4)
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (11)		$ (11)		$ (4)

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Sep. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	629,328,058	628,669,356
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Derivative [Line Items]
Derivative fair value	$ 160	$ 106
Collateral	160
Southern California Gas Company
Derivative [Line Items]
Derivative fair value	157	$ 69
Collateral	$ 157

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

Total

Preferred stock

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

Southern California Gas Company

Preferred stock

Southern California Gas Company

Common stock

Southern California Gas Company

Retained earnings

Southern California Gas Company

Accumulated other comprehensive income (loss)

Beginning Balance at Dec. 31, 2021

$ 27,419

$ 889

$ 11,862

$ 13,548

$ (318)

$ 5,442

$ 22

$ 1,666

$ 3,785

$ (31)

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

Net income

1,877

1,690

340

Other comprehensive (loss) income

245

189

Dividends declared:

Preferred dividends

(1)

Equity contribution from Sempra

650

Ending balance at Sep. 30, 2022

29,289

889

12,138

14,123

(120)

6,434

2,316

4,124

(28)

Beginning Balance at Jun. 30, 2022

29,053

889

12,121

13,998

(167)

6,015

1,816

4,206

(29)

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

Net income

561

496

(82)

Other comprehensive (loss) income

Dividends declared:

Preferred dividends

Equity contribution from Sempra

500

Ending balance at Sep. 30, 2022

29,289

889

12,138

14,123

(120)

6,434

2,316

4,124

(28)

Beginning Balance at Dec. 31, 2022

29,256

^[1]

889

12,160

14,201

(135)

6,698

2,316

4,384

(24)

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

Net income

2,762

2,327

532

Other comprehensive (loss) income

333

121

Dividends declared:

Preferred dividends

(1)

Ending balance at Sep. 30, 2023

33,258

889

12,038

15,371

(60)

7,231

2,316

4,915

(22)

Beginning Balance at Jun. 30, 2023

31,014

889

12,044

15,024

(121)

7,215

2,316

4,899

(22)

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

Net income

854

732

Other comprehensive (loss) income

309

107

Dividends declared:

Preferred dividends

Ending balance at Sep. 30, 2023

$ 33,258

$ 889

$ 12,038

$ 15,371

$ (60)

$ 7,231

$ 22

$ 2,316

$ 4,915

$ (22)

[1]	Derived from audited financial statements.

- Definition

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

+ References

+ Details

- Definition

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

+ References

+ Details

- Definition

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

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
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-Name Accounting Standards Codification
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Related Party Transaction [Line Items]
Revenues	$ 3,334	$ 3,617	$ 13,229	$ 10,984
Interest income	19	18	60	58
Interest expense	312	282	995	796
Related Party
Related Party Transaction [Line Items]
Revenues	10	10	34	32
Interest income	0	2	0	16
Interest expense	3	4	11	12
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Interest income	7	2	12	3
Interest expense	126	113	367	333
Operating revenues	1,442	1,569	4,357	4,413
San Diego Gas and Electric Company \| Related Party
Related Party Transaction [Line Items]
Operating revenues	5	4	15	12
Cost of sales	25	17	82	67
Southern California Gas Company
Related Party Transaction [Line Items]
Interest income	2	3	7	4
Interest expense	70	50	210	135
Operating revenues	1,313	1,385	6,574	4,879
Southern California Gas Company \| Related Party
Related Party Transaction [Line Items]
Operating revenues	29	24	91	73
Cost of sales	$ 2	$ (1)	$ 37	$ (5)

- Definition

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

+ References + Details

GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022	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	$ 328	$ 316

CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Dividends declared per share of common stock (in dollars per share)	$ 0.60	$ 0.57	$ 1.79	$ 1.72
San Diego Gas and Electric Company
Dividends declared per share of common stock (in dollars per share)	$ 0.86	$ 0.86	$ 0.86	$ 0.86

DERIVATIVE FINANCIAL INSTRUMENTS

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

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

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

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

HEDGE ACCOUNTING

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

ENERGY DERIVATIVES

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

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

in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power.

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

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

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

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

September 30, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

441

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

347

224

INTEREST RATE DERIVATIVES

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

In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap.

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

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

INTEREST RATE DERIVATIVES

(Dollars in millions)

September 30, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,454

2023-2048

294

2023-2034

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

FOREIGN CURRENCY DERIVATIVES

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

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

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


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	September 30, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	150		2023-2025	111		2023-2024

FINANCIAL STATEMENT PRESENTATION

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


DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	September 30, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	15	$	363	$	—	$	—
Foreign exchange instruments	—		1		(8)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	175		25		(172)		(29)
Associated offsetting commodity contracts	(166)		(22)		166		22
Commodity contracts subject to rate recovery	22		15		(171)		(6)
Associated offsetting commodity contracts	(16)		(3)		16		3
Associated offsetting cash collateral	—		—		—		1
Net amounts presented on the balance sheet	30		379		(169)		(9)
Additional cash collateral for commodity contracts not subject to rate recovery	89		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	82		—		—		—
Total(2)	$	201	$	379	$	(169)	$	(9)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	18	$	15	$	(13)	$	(4)
Associated offsetting commodity contracts	(12)		(3)		12		3
Associated offsetting cash collateral	—		—		—		1
Net amounts presented on the balance sheet	6		12		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	80		—		—		—
Total(2)	$	86	$	12	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4	$	—	$	(158)	$	(2)
Associated offsetting commodity contracts	(4)		—		4		—
Net amounts presented on the balance sheet	—		—		(154)		(2)
Additional cash collateral for commodity contracts subject to rate recovery	2		—		—		—
Total	$	2	$	—	$	(154)	$	(2)

(1) Included in Other Current Assets for SoCalGas.

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


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

(1) Included in Other Current Assets for SoCalGas.

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

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


CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended September 30,					Three months ended September 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	320	$	4	Interest Expense	$	(1)	$	(2)
Interest rate instruments	32		68		Equity Earnings(1)	12		(1)
Foreign exchange instruments	8		2		Revenues: Energy- Related Businesses	—		—
					Other Income (Expense), Net	1		—
Foreign exchange instruments	7		1		Equity Earnings(1)	1		—
Interest rate and foreign exchange instruments	—		—		Other Income (Expense), Net	—		(3)
Total	$	367	$	75		$	13	$	(6)



	Nine months ended September 30,					Nine months ended September 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	337	$	39	Interest Expense	$	(1)	$	(1)
Interest rate instruments	56		212		Equity Earnings(1)	33		(28)
Foreign exchange instruments	—		(1)		Revenues: Energy- Related Businesses	—		2
					Other Income (Expense), Net	(1)		(1)
Foreign exchange instruments	1		(1)		Equity Earnings(1)	(1)		1
Interest rate and foreign exchange instruments	7		13		Interest Expense	1		1
					Other Income (Expense), Net	6		3
Total	$	401	$	262		$	37	$	(23)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

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

For Sempra, we expect that net gains before NCI of $48 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $22 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 September 30, 2023 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 16 years.

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


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended September 30,				Nine months ended September 30,
	Location	2023		2022		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	83	$	(227)	$	785	$	(455)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(125)		(11)		(172)		(15)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	23		16		5		10
Interest rate instrument	Interest Expense	—		—		(47)		—
Total		$	(19)	$	(222)	$	571	$	(460)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	23	$	16	$	5	$	10
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(125)	$	(11)	$	(172)	$	(15)

CREDIT RISK RELATED CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at September 30, 2023 and December 31, 2022 was $160 million and $106 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at September 30, 2023 and December 31, 2022 was $157 million and $69 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at September 30, 2023 or December 31, 2022. At September 30, 2023, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $160 million and $157 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.

REGULATORY MATTERS - FERC RATE MATTERS (Details) - San Diego Gas and Electric Company	9 Months Ended
	Sep. 30, 2023
Public Utilities, General Disclosures [Line Items]
FERC requirement to maintain common equity ratio, at or above (percent)	10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)	10.10%
FERC requirement, additional basis spread	0.50%

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

Sep. 30, 2023

Dec. 31, 2022

Noncontrolling Interest [Line Items]

Other noncontrolling interests

$ 5,000

$ 2,121

^[1]

SI Partners | Sempra Infrastructure

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

30.00%

Other noncontrolling interests

$ 4,011

$ 2,060

SI Partners subsidiaries | Sempra Infrastructure

Noncontrolling Interest [Line Items]

Other noncontrolling interests

$ 989

$ 61

SI Partners subsidiaries | Sempra Infrastructure | Minimum

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

0.10%

SI Partners subsidiaries | Sempra Infrastructure | Maximum

Noncontrolling Interest [Line Items]

Ownership interest (as a percent)

42.00%

16.60%

[1]	Derived from audited financial statements.

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 48
Cash flow hedge gain (loss) to be reclassified, NCI	$ 22
Term of interest rate cash flow hedge (in years)	24 years
Southern California Gas Company
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee
Derivative [Line Items]
Term of interest rate cash flow hedge (in years)	16 years

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance	$ 1,383	$ 1,206	$ 3,958	$ 3,454
Interest expense	(312)	(282)	(995)	(796)
Energy-related businesses	596	673	2,338	1,710
Other Income (Expense), Net	3	(40)	75	(3)
Income before income taxes and equity earnings	323	165	2,175	1,194
Income tax benefit (expense)	52	(21)	(499)	(435)
Net income	854	561	2,762	1,877
Earnings Attributable to Noncontrolling Interests	(122)	(65)	(435)	(187)
Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(70)	(50)	(210)	(135)
Other Income (Expense), Net	(2)	(43)	(9)	(5)
Income before income taxes and equity earnings	11	(110)	600	415
Income tax benefit (expense)	5	28	(68)	(75)
Net income	16	(82)	532	340
San Diego Gas and Electric Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(126)	(113)	(367)	(333)
Other Income (Expense), Net	25	12	75	68
Income before income taxes and equity earnings	259	306	712	822
Income tax benefit (expense)	15	(35)	4	(141)
Net income	274	271	716	681
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	(4)	7	(11)	27
Reclassification out of Accumulated Other Comprehensive Income \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	0	1	2	3
Reclassification out of Accumulated Other Comprehensive Income \| San Diego Gas and Electric Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	0	1	0	1
Reclassification out of Accumulated Other Comprehensive Income \| Foreign currency translation adjustments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance			0	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	(13)	6	(37)	23
Income tax benefit (expense)	2	(2)	5	(7)
Net income	(11)	4	(32)	16
Earnings attributable to common shares	(5)	5	(14)	20
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income			1	2
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	2	1	1
Equity earnings	(12)	1	(33)	28
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate instruments \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense			1	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	(1)	0	1	(1)
Energy-related businesses			0	(2)
Other Income (Expense), Net	(1)	0	1	1
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest \| Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense			(1)	(1)
Other Income (Expense), Net	0	3	(6)	(3)
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	6	1	18	4
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	1	2	2	6
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost			0	1
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss \| San Diego Gas and Electric Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost	0	1	0	1
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of prior service cost
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	1	1	2	3
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of prior service cost \| Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service cost	0	1	1	1
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	2	3	4	9
Income tax benefit (expense)	(1)	(1)	(1)	(3)
Net income	$ 1	$ 2	$ 3	$ 6

CONDENSED BALANCE SHEETS - SoCalGas (Parentheticals) - shares	Sep. 30, 2023	Dec. 31, 2022
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	1,125,000,000	1,125,000,000
Common stock, shares outstanding (in shares)	629,328,058	628,669,356
Southern California Gas Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	862,043	862,043
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,300,000	91,300,000

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS & ENVIRONMENTAL ISSUES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)
Loss Contingencies [Line Items]
Potential monetary sanctions threshold	$ 1
Potential monetary sanctions threshold (as a percent)	1.00%
Environmental cost, potential monetary sanctions threshold, actual amount	$ 53
Sempra Infrastructure \| Natural Gas Storage and Transportation Contracts
Loss Contingencies [Line Items]
Change since 2022	877
Change in 2023	(29)
Change in 2024	38
Change in 2025	35
Change in 2026	33
Change in 2027	30
Change thereafter	770
Sempra Infrastructure \| Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Change in 2023	(980)
Change in 2024	(62)
Change in 2025	(45)
Change in 2026	(47)
Change in 2027	(58)
Change thereafter	(136)
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	19
San Diego Gas and Electric Company \| Purchased-Power Contracts
Loss Contingencies [Line Items]
Change since 2022	482
Change in 2023	14
Change in 2024	3
Change in 2025	13
Change in 2026	32
Change in 2027	33
Change thereafter	387
Southern California Gas Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	$ 14

DEBT AND CREDIT FACILITIES - COMMITTED LINES OF CREDIT (Details) $ in Millions	1 Months Ended			12 Months Ended
	Oct. 31, 2023 lender	Sep. 30, 2023 USD ($)	Aug. 31, 2023 USD ($)	Oct. 31, 2028 USD ($) lender	Sep. 29, 2023 USD ($)	Mar. 31, 2023 USD ($)
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 9,900
Available unused credit		7,933
Forecast
Line of Credit Facility [Line Items]
Number of lenders \| lender				22
Subsequent Event
Line of Credit Facility [Line Items]
Number of lenders \| lender	23
Letters of credit outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		(25)
Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		(1,391)
Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		(551)
Sempra
Line of Credit Facility [Line Items]
Maximum borrowing capacity		4,000
Available unused credit		3,030
Sempra \| Forecast
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 3,845
Sempra \| 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		(970)
Sempra \| Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		0
San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		1,500
Available unused credit		1,500
San Diego Gas and Electric Company \| Forecast
Line of Credit Facility [Line Items]
Maximum borrowing capacity				1,442
San Diego Gas and Electric Company \| Letters of credit outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		0
San Diego Gas and Electric Company \| Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		0
San Diego Gas and Electric Company \| Amounts outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		0
Southern California Gas Company
Line of Credit Facility [Line Items]
Maximum borrowing capacity		1,200
Available unused credit		779
Southern California Gas Company \| Forecast
Line of Credit Facility [Line Items]
Maximum borrowing capacity				$ 1,153
Southern California Gas Company \| Letters of credit outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		0
Southern California Gas Company \| Commercial paper outstanding
Line of Credit Facility [Line Items]
Line of credit outstanding		(421)
Southern California Gas Company \| 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			$ 350
Available unused credit		$ 150
Variable percentage rate (in percent)		0.80%
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due September 2025 \| 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	$ 1,500
Available unused credit		1,000
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2026 \| Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Variable percentage rate (in percent)			0.10%
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2026 \| 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		1,299
SI Partners and IEnova \| IEnova and SI Partners Committed Line Of Credit Due August 2028 \| 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		0
SI Partners and IEnova \| Amounts outstanding \| IEnova and SI Partners Committed Line Of Credit Due August 2028
Line of Credit Facility [Line Items]
Line of credit outstanding		(201)
SI Partners and IEnova \| Line of Credit \| IEnova And SI Partners Committed Line Of Credit Due December 2023
Line of Credit Facility [Line Items]
Termination of debt		150
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		175
Port Arthur LNG \| Port Arthur LNG Committed Line Of Credit Due 2030 \| Letters of credit outstanding
Line of Credit Facility [Line Items]
Maximum borrowing capacity						$ 200
Line of credit outstanding		(25)
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
Port Arthur LNG \| Line of Credit \| Port Arthur LNG Committed Line Of Credit Due 2030
Line of Credit Facility [Line Items]
Maximum borrowing capacity						$ 200

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Schedule of Equity Method Investments [Line Items]
Net income	$ 854	$ 561	$ 2,762	$ 1,877
Equity Method Investment, Nonconsolidated Investee or Group of Investees \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,592	1,438	4,227	3,980
Operating expenses	(1,007)	(929)	(3,007)	(2,734)
Operating income (loss)	585	509	1,220	1,246
Interest expense	(140)	(115)	(396)	(331)
Income tax expense	(81)	(70)	(148)	(164)
Net income	376	315	672	732
Noncontrolling interest held by Texas Transmission Investment LLC	(75)	(62)	(135)	(146)
Earnings attributable to Sempra Energy	$ 301	$ 253	$ 537	$ 586

INVESTMENTS IN UNCONSOLIDATED ENTITIES

9 Months Ended

Sep. 30, 2023

Investments [Abstract]

INVESTMENTS IN UNCONSOLIDATED ENTITIES

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

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

SEMPRA TEXAS UTILITIES

Oncor Holdings

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

In the nine months ended September 30, 2023 and 2022, Sempra contributed $270 million and $256 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $323 million and $255 million, respectively, to Sempra.

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


SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Operating revenues	$	1,592	$	1,438	$	4,227	$	3,980
Operating expenses	(1,007)		(929)		(3,007)		(2,734)
Income from operations	585		509		1,220		1,246
Interest expense	(140)		(115)		(396)		(331)
Income tax expense	(81)		(70)		(148)		(164)
Net income	376		315		672		732
Noncontrolling interest held by Texas Transmission Investment LLC	(75)		(62)		(135)		(146)
Earnings attributable to Sempra(1)	301		253		537		586

SEMPRA INFRASTRUCTURE

Cameron LNG JV

In the nine months ended September 30, 2023 and 2022, Sempra Infrastructure contributed $11 million and $19 million, respectively, to Cameron LNG JV, and Cameron LNG JV distributed $339 million and $388 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 September 30, 2023, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra Infrastructure’s investment in Cameron LNG JV. The guarantee will terminate upon full repayment of Cameron LNG JV’s debt, scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA.

Sempra Support Agreement for CFIN

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

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

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

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

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

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

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

In exchange for this guarantee, the external lenders pay a guarantee fee that is based on the credit rating of Sempra’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra Infrastructure recognizes as interest income as earned. Sempra’s maximum exposure to loss is the bank debt plus any accrued and unpaid interest and related fees, subject to a liability cap of 130% of the bank debt, or $979 million. We measure the Support Agreement at fair value, net of related guarantee fees, on a recurring basis (see Note 8). At September 30, 2023, the fair value of the Support Agreement was $18 million, of which $7 million is included in Other Current Assets and $11 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

TAG

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

IMG

In the nine months ended September 30, 2023, IMG distributed $6 million to Sempra Infrastructure.

SEGMENT INFORMATION (Tables)

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Segment Information


SEGMENT INFORMATION
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
REVENUES
SDG&E	$	1,442	$	1,569	$	4,357	$	4,413
SoCalGas	1,313		1,385		6,574		4,879
Sempra Infrastructure	629		697		2,485		1,810
All other	—		1		—		1
Adjustments and eliminations	—		—		(1)		—
Intersegment revenues(1)	(50)		(35)		(186)		(119)
Total	$	3,334	$	3,617	$	13,229	$	10,984
DEPRECIATION AND AMORTIZATION
SDG&E	$	280	$	247	$	810	$	730
SoCalGas	211		190		625		565
Sempra Infrastructure	71		67		210		199
All other	1		2		6		6
Total	$	563	$	506	$	1,651	$	1,500
INTEREST INCOME
SDG&E	$	7	$	2	$	12	$	3
SoCalGas	2		3		7		4
Sempra Infrastructure	4		7		25		37
All other	7		6		17		14
Intercompany eliminations	(1)		—		(1)		—
Total	$	19	$	18	$	60	$	58
INTEREST EXPENSE
SDG&E	$	126	$	113	$	367	$	333
SoCalGas	70		50		210		135
Sempra Infrastructure	7		39		127		98
All other	109		81		292		232
Intercompany eliminations	—		(1)		(1)		(2)
Total	$	312	$	282	$	995	$	796
INCOME TAX (BENEFIT) EXPENSE
SDG&E	$	(15)	$	35	$	(4)	$	141
SoCalGas	(5)		(28)		68		75
Sempra Texas Utilities	—		1		—		1
Sempra Infrastructure	24		58		555		219
All other	(56)		(45)		(120)		(1)
Total	$	(52)	$	21	$	499	$	435
EQUITY EARNINGS
Equity earnings, before income tax:
Sempra Texas Utilities	$	2	$	1	$	5	$	6
Sempra Infrastructure	131		133		413		430

	133		134		418		436
Equity earnings, net of income tax:
Sempra Texas Utilities	305		257		548		603
Sempra Infrastructure	41		26		120		79
	346		283		668		682
Total	$	479	$	417	$	1,086	$	1,118


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	274	$	271	$	716	$	681
SoCalGas	16		(82)		531		339
Sempra Texas Utilities	305		256		548		604
Sempra Infrastructure	223		114		746		392
All other	(97)		(74)		(248)		(360)
Total	$	721	$	485	$	2,293	$	1,656
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,893	$	1,651
SoCalGas					1,451		1,394
Sempra Infrastructure					2,725		489
All other					5		6
Total					$	6,074	$	3,540

					September 30, 2023		December 31, 2022
ASSETS
SDG&E					$	28,502	$	26,422
SoCalGas					23,069		22,346
Sempra Texas Utilities					14,269		13,781
Sempra Infrastructure					19,722		15,760
All other					1,205		1,376
Intersegment receivables					(1,032)		(1,111)
Total					$	85,735	$	78,574
EQUITY METHOD INVESTMENTS
Sempra Texas Utilities					$	14,260	$	13,772
Sempra Infrastructure					2,096		1,905
Total					$	16,356	$	15,677

DEBT AND CREDIT FACILITIES

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

DEBT AND CREDIT FACILITIES

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

SHORT-TERM DEBT

Committed Lines of Credit

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


COMMITTED LINES OF CREDIT
(Dollars in millions)
		September 30, 2023
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Letters of credit outstanding		Available unused credit
Sempra	October 2028(1)	$	4,000	$	(970)	$	—	$	—	$	3,030
SDG&E	October 2028(1)	1,500		—		—		—		1,500
SoCalGas	October 2028(1)	1,200		(421)		—		—		779
SI Partners and IEnova	September 2025(2)	500		—		(350)		—		150
SI Partners and IEnova	August 2026(3)	1,000		—		—		—		1,000
SI Partners and IEnova	August 2028(4)	1,500		—		(201)		—		1,299
Port Arthur LNG	March 2030	200		—		—		(25)		175
Total		$	9,900	$	(1,391)	$	(551)	$	(25)	$	7,933

(4) In August 2023, the facility was amended to extend the expiration date from February 2024 to August 2028.

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

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

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

Uncommitted Line of Credit

ECA LNG Phase 1 has an uncommitted line of credit, which is generally used for working capital requirements, with an aggregate capacity of $200 million of which $37 million was outstanding at September 30, 2023. The amounts outstanding are before reductions of any unamortized discounts. Borrowings can be in U.S. dollars or Mexican pesos. At September 30, 2023, outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps. In June 2023, the facility was amended to extend the expiration date to August 2024 and replace the London Interbank Offered Rate reference rate plus 105 bps with the SOFR reference rate plus 115 bps. As such, borrowings made in U.S. dollars bear interest at a variable rate based on the one-month or three-month SOFR plus 115 bps.

Uncommitted Letters of Credit

Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At September 30, 2023, we had $508 million in standby letters of credit outstanding under these agreements.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		September 30, 2023
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2024 - May 2024	$	15
SoCalGas	March 2024 - November 2024	20
Sempra Infrastructure	October 2023 - October 2043	307
Parent and other	March 2024 - September 2024	166
Total		$	508

Term Loan

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

Weighted-Average Interest Rates

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


WEIGHTED-AVERAGE INTEREST RATES

	September 30, 2023		December 31, 2022
Sempra	5.86	%	5.57	%
SDG&E	—		4.76
SoCalGas	5.37		4.71

LONG-TERM DEBT

SDG&E

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

In August 2023, SDG&E issued $600 million aggregate principal amount of 4.95% green first mortgage bonds due in full upon maturity on August 15, 2028 and received proceeds of $593 million (net of debt discount, underwriting discounts and debt issuance costs of $7 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 intends to use the net proceeds to finance or refinance investments in eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation.

SoCalGas

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

Sempra

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

Sempra Infrastructure

ECA LNG Phase 1

ECA LNG Phase 1 has a five-year loan agreement with a syndicate of seven external lenders that matures in December 2025 for an aggregate principal amount of up to $1.3 billion. IEnova and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest of 83.4% and 16.6%, respectively. At September 30, 2023 and December 31, 2022, $782 million and $575 million, respectively, of borrowings from external lenders were outstanding under the loan agreement, with a weighted-average interest rate of 8.35% and 7.54%, respectively.

Port Arthur LNG

In March 2023, Port Arthur LNG entered into a term loan facility agreement with a syndicate of lenders for an aggregate principal amount of approximately $6.8 billion. Proceeds from the loans will be used to finance the cost of construction of the PA LNG Phase 1 project. The loans mature on March 20, 2030 and bear interest by reference to Term SOFR, plus the applicable margin and a credit adjustment spread. The applicable margin prior to completion of the PA LNG Phase 1 project (which occurs upon the satisfaction or waiver of a series of customary operational, technical, environmental and social and other tests and conditions that generally would not be fully met until after the commercial operations date) is 2.00% and on completion and thereafter is 2.25%. The principal amounts outstanding on the loans must be repaid in quarterly installments, commencing on the earlier of (i) the first quarterly payment date occurring more than three calendar months following completion of the PA LNG Phase 1 project and (ii) April 20, 2029. Under the terms of the loan agreement, at least 60% of the projected outstanding balance is required to be hedged during construction and over the underlying 20-year notional amortization period. As we discuss in Note 7, Port Arthur LNG entered into hedging instruments in satisfaction of this requirement in March 2023. An upfront equity funding amount of $4.7 billion is required to have been contributed to Port Arthur LNG for construction costs as a condition to the initial advance of term loans under the agreement (other than advances for fees, interest, expenses and certain other specified costs). Port Arthur LNG paid $200 million in debt issuance costs at closing. Additionally, the loan agreement and the related working capital facility agreement that we discuss above require payment of commitment fees calculated at a rate per annum equal to 30% of the applicable margin for Term SOFR loans multiplied by the outstanding debt commitments, and additional administrative fees. At September 30, 2023, $243 million of borrowings were outstanding under the loan agreement, with an all-in weighted-average interest rate of 5.71%.

In connection with this loan agreement, SI Partners and ConocoPhillips have collectively provided commitments for approximately $2.8 billion in equity funding for the benefit of Port Arthur LNG for their respective affiliate’s share of the equity funding of anticipated construction costs of the PA LNG Phase 1 project in excess of the upfront equity funding amount of $4.7 billion. The amount of each commitment is based on each of SI Partners’ and ConocoPhillips’ proportionate indirect ownership interest in Port Arthur LNG of 70% and 30%, respectively, as of the March 2023 loan agreement. The obligation under these guarantees will be reduced as their respective affiliates fund their direct proportionate interest of capital calls. Such equity funding can be called upon by Port Arthur LNG to fund project costs or, upon the taking of an enforcement action under the terms of Port Arthur LNG’s finance documents, to pay its senior debt obligations.

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

interests of, Port Arthur LNG.

- Definition

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.

+ References

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

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(c))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480678/235-10-S99-1

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Topic 470
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org//470/tableOfContent

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1B
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1B

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1B
-Subparagraph (g)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1B

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1B
-Subparagraph (i)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1B

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1C
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1C

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1C
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1C

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1C
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1C

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1E
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1E

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1I
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1I
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1I
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481139/470-20-50-1I

+ Details

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

9 Months Ended

Sep. 30, 2023

Dec. 31, 2022

Variable Interest Entities [Line Items]

Property plant and equipment, net

$ 53,172

$ 47,782

^[1]

Finance lease obligations

1,346

1,343

Equity method investment

14,148

13,665

^[1]

Assets

85,735

78,574

^[1]

Oncor Holdings | Sempra Texas Utilities

Variable Interest Entities [Line Items]

Equity method investment

14,148

13,665

Cameron LNG Holdings | Sempra Infrastructure

Variable Interest Entities [Line Items]

Equity method investment

989

886

San Diego Gas and Electric Company

Variable Interest Entities [Line Items]

Property plant and equipment, net

23,088

21,806

^[1]

Finance lease obligations

1,234

1,256

Assets

$ 28,502

26,422

^[1]

IEnova | ECA LNG JV

Variable Interest Entities [Line Items]

Ownership percentage in consolidated entity (in percentage)

83.40%

Subsidiary of TOTAL SE | ECA LNG JV

Variable Interest Entities [Line Items]

Ownership percentage in consolidated entity (in percentage)

16.60%

Variable Interest Entity, Not Primary Beneficiary | Sempra Infrastructure

Variable Interest Entities [Line Items]

Maximum exposure under guarantor obligations

$ 979

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

Variable Interest Entities [Line Items]

Property plant and equipment, net

1,174

1,194

Finance lease obligations

1,174

1,194

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

Variable Interest Entities [Line Items]

Assets

1,430

1,099

Liabilities

924

$ 685

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

Variable Interest Entities [Line Items]

Assets

3,830

Liabilities

$ 788

[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash and Cash Equivalents


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	September 30, 2023		December 31, 2022
Cash and cash equivalents	$	1,149	$	370
Restricted cash, current	238		40
Restricted cash, noncurrent	104		52
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	1,491	$	462

Accounts Receivable, Allowance for Credit Loss Table

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


CHANGES IN ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2023		2022
Sempra:
Allowances for credit losses at January 1	$	181	$	136
Provisions for expected credit losses	374		111
Write-offs	(74)		(57)
Allowances for credit losses at September 30	$	481	$	190
SDG&E:
Allowances for credit losses at January 1	$	78	$	66
Provisions for expected credit losses	96		51
Write-offs	(34)		(30)
Allowances for credit losses at September 30	$	140	$	87
SoCalGas:
Allowances for credit losses at January 1	$	98	$	69
Provisions for expected credit losses	276		58
Write-offs	(40)		(27)
Allowances for credit losses at September 30	$	334	$	100

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


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	September 30,		December 31,
	2023		2022
Sempra:
Accounts receivable – trade, net	$	432	$	140
Accounts receivable – other, net	48		40
Other long-term assets	1		1
Total allowances for credit losses	$	481	$	181
SDG&E:
Accounts receivable – trade, net	$	113	$	52
Accounts receivable – other, net	26		25
Other long-term assets	1		1
Total allowances for credit losses	$	140	$	78
SoCalGas:
Accounts receivable – trade, net	$	312	$	83
Accounts receivable – other, net	22		15
Total allowances for credit losses	$	334	$	98

Inventory Table

The components of inventories are as follows:


INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Natural gas	$	160	$	106	$	1	$	1	$	144	$	74
LNG	9		62		—		—		—		—
Materials and supplies	282		235		146		133		116		85
Total	$	451	$	403	$	147	$	134	$	260	$	159

Capitalized Financing Costs Table

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


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra	$	128	$	65	$	311	$	182
SDG&E	28		30		90		84
SoCalGas	20		19		55		54

Net Periodic Benefit Cost Table


NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	25	$	27	$	3	$	4
Interest cost	39		29		9		7
Expected return on assets	(42)		(46)		(17)		(16)
Amortization of:
Prior service cost (credit)	2		3		(1)		(1)
Actuarial loss (gain)	3		8		(5)		(4)
Net periodic benefit cost (credit)	27		21		(11)		(10)
Regulatory adjustments	30		87		10		10
Total expense (income) recognized	$	57	$	108	$	(1)	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	82	$	110	$	10	$	17
Interest cost	118		88		28		21
Expected return on assets	(127)		(137)		(52)		(48)
Amortization of:
Prior service cost (credit)	4		8		(2)		(2)
Actuarial loss (gain)	7		19		(17)		(11)
Net periodic benefit cost (credit)	84		88		(33)		(23)
Regulatory adjustments	88		84		32		23
Total expense (income) recognized	$	172	$	172	$	(1)	$	—


NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	8	$	8	$	1	$	1
Interest cost	10		7		2		1
Expected return on assets	(9)		(13)		(2)		(2)
Amortization of:
Actuarial loss (gain)	2		—		—		(1)
Net periodic benefit cost (credit)	11		2		1		(1)
Regulatory adjustments	3		24		(1)		1
Total expense recognized	$	14	$	26	$	—	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	24	$	28	$	2	$	4
Interest cost	30		20		6		4
Expected return on assets	(29)		(35)		(6)		(7)
Amortization of:
Actuarial loss (gain)	4		1		(1)		(2)
Net periodic benefit cost (credit)	29		14		1		(1)
Regulatory adjustments	11		26		(1)		1
Total expense recognized	$	40	$	40	$	—	$	—


NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension				PBOP
	Three months ended September 30,
	2023		2022		2023		2022
Service cost	$	15	$	16	$	2	$	3
Interest cost	24		20		7		5
Expected return on assets	(29)		(30)		(14)		(13)
Amortization of:
Prior service cost (credit)	1		2		(1)		(1)
Actuarial loss (gain)	1		6		(5)		(3)
Net periodic benefit cost (credit)	12		14		(11)		(9)
Regulatory adjustments	27		63		11		9
Total expense recognized	$	39	$	77	$	—	$	—

	Nine months ended September 30,
	2023		2022		2023		2022
Service cost	$	49	$	72	$	7	$	13
Interest cost	75		61		21		16
Expected return on assets	(89)		(94)		(44)		(40)
Amortization of:
Prior service cost (credit)	3		6		(2)		(2)
Actuarial loss (gain)	1		14		(15)		(9)
Net periodic benefit cost (credit)	39		59		(33)		(22)
Regulatory adjustments	77		58		33		22
Total expense recognized	$	116	$	117	$	—	$	—

Schedule of Accumulated Other Comprehensive Income (Loss) Table

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


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and PBOP		Total AOCI
	Three months ended September 30, 2023 and 2022
Sempra:
Balance at June 30, 2023	$	(38)	$	14	$	(97)	$	(121)
OCI before reclassifications	(5)		116		—		111
Amounts reclassified from AOCI(2)	—		(51)		1		(50)
Net OCI(2)	(5)		65		1		61
Balance at September 30, 2023	$	(43)	$	79	$	(96)	$	(60)

Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
OCI before reclassifications	—		40		—		40
Amounts reclassified from AOCI	—		5		2		7
Net OCI	—		45		2		47
Balance at September 30, 2022	$	(65)	$	15	$	(70)	$	(120)
SDG&E:




Balance at June 30, 2023 and September 30, 2023					$	(7)	$	(7)

Balance at June 30, 2022					$	(10)	$	(10)
Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2022					$	(9)	$	(9)
SoCalGas:
Balance at June 30, 2023 and September 30, 2023			$	(11)	$	(11)	$	(22)






Balance at June 30, 2022			$	(12)	$	(17)	$	(29)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at September 30, 2022			$	(12)	$	(16)	$	(28)

(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
	Nine months ended September 30, 2023 and 2022
Sempra:
Balance at December 31, 2022	$	(59)	$	10	$	(86)	$	(135)
OCI before reclassifications	16		129		(13)		132
Amounts reclassified from AOCI(2)	—		(60)		3		(57)
Net OCI(2)	16		69		(10)		75
Balance at September 30, 2023	$	(43)	$	79	$	(96)	$	(60)

Balance at December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		151		7		162
Amounts reclassified from AOCI(3)	10		20		6		36
Net OCI(3)	14		171		13		198
Balance at September 30, 2022	$	(65)	$	15	$	(70)	$	(120)
SDG&E:




Balance at December 31, 2022 and September 30, 2023					$	(7)	$	(7)

Balance at December 31, 2021					$	(10)	$	(10)

Amounts reclassified from AOCI					1		1
Net OCI					1		1
Balance at September 30, 2022					$	(9)	$	(9)
SoCalGas:
Balance at December 31, 2022			$	(12)	$	(12)	$	(24)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance at September 30, 2023			$	(11)	$	(11)	$	(22)

Balance at December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		2		3
Net OCI			1		2		3
Balance at September 30, 2022			$	(12)	$	(16)	$	(28)

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

Reclassifications out of AOCI Table


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about AOCI	Amounts reclassified from AOCI				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended September 30,
	2023		2022
Sempra:


Financial instruments:
Interest rate instruments	$	1	$	2	Interest Expense
Interest rate instruments	(12)		1		Equity Earnings(1)

Foreign exchange instruments	(1)		—		Other Income (Expense), Net

Foreign exchange instruments	(1)		—		Equity Earnings
Interest rate and foreign exchange instruments	—		3		Other Income (Expense), Net
Total, before income tax	(13)		6
	2		(2)		Income Tax Benefit (Expense)
Total, net of income tax	(11)		4
	6		1		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(5)	$	5

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

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

Total reclassifications for the period, net of income tax and after NCI	$	(4)	$	7
SDG&E:
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income, Net


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



Pension and PBOP(2):

Amortization of prior service cost	$	—	$	1	Other Expense, Net






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

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

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


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

Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense
Interest rate instruments	(33)		28		Equity Earnings(1)
Foreign exchange instruments	—		(2)		Revenues: Energy-Related Businesses
	1		1		Other Income (Expense), Net
Foreign exchange instruments	1		(1)		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		(1)		Interest Expense
	(6)		(3)		Other Income (Expense), Net
Total, before income tax	(37)		23
	5		(7)		Income Tax Benefit (Expense)
Total, net of income tax	(32)		16
	18		4		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	(14)	$	20

Pension and PBOP(2):
Amortization of actuarial loss	$	2	$	6	Other Income (Expense), Net
Amortization of prior service cost	2		3		Other Income (Expense), Net
Total, before income tax	4		9
	(1)		(3)		Income Tax Benefit (Expense)
Total, net of income tax	$	3	$	6

Total reclassifications for the period, net of income tax and after NCI	$	(11)	$	27
SDG&E:
Pension and PBOP(2):
Amortization of actuarial loss	$	—	$	1	Other Income, Net

Total reclassifications for the period, net of income tax	$	—	$	1
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	1	Interest Expense

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


Total, net of income tax	$	1	$	2

Total reclassifications for the period, net of income tax	$	2	$	3

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

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

Ownership Interests Held By Others Table


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Sempra Infrastructure:
SI Partners	30.0	%	30.0	%	$	4,011	$	2,060
SI Partners subsidiaries(1)	0.1 - 42.0		0.1 - 16.6		989		61
Total Sempra					$	5,000	$	2,121

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

Earnings Per Share Computations Table


EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Numerator:
Earnings attributable to common shares	$	721	$	485	$	2,293	$	1,656

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	630,036		629,447		629,963		630,603
Dilutive effect of stock options and RSUs(2)	2,288		2,728		2,268		2,311
Weighted-average common shares outstanding for diluted EPS	632,324		632,175		632,231		632,914

EPS:
Basic	$	1.14	$	0.77	$	3.64	$	2.63
Diluted	$	1.14	$	0.77	$	3.63	$	2.62

Transactions with Affiliates Table

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


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	September 30, 2023		December 31, 2022
Sempra:
Tax sharing arrangement with Oncor Holdings	$	34	$	41
Various affiliates	8		13
Total due from unconsolidated affiliates – current	$	42	$	54

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

Sempra Infrastructure(1):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	—	$	(40)
5.5% Note due January 14, 2025	(24)		(23)
5.5% Note due July 16, 2025	(22)		(21)
5.5% Note due January 14, 2026	(20)		(19)
5.5% Note due July 14, 2026	(11)		(11)
5.5% Note due January 19, 2027	(14)		—
5.5% Note due July 21, 2027	(17)		—
TAG – 5.74% Note due December 17, 2029	(195)		(187)
Total due to unconsolidated affiliates – noncurrent	$	(303)	$	(301)
SDG&E:
SoCalGas	$	8	$	—
Total due from unconsolidated affiliates – current	$	8	$	—

Sempra	$	(38)	$	(49)
SoCalGas	—		(72)
Various affiliates	(11)		(14)
Total due to unconsolidated affiliates – current	$	(49)	$	(135)

Income taxes due (to) from Sempra(2)	$	(43)	$	10
SoCalGas:
SDG&E	$	—	$	72
Various affiliates	1		5
Total due from unconsolidated affiliates – current	$	1	$	77

Sempra	$	(30)	$	(36)
SDG&E	(8)		—
Total due to unconsolidated affiliates – current	$	(38)	$	(36)

Income taxes due to Sempra(2)	$	(6)	$	(16)

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

The following table summarizes income statement information from unconsolidated affiliates.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra:
Revenues	$	10	$	10	$	34	$	32
Interest income	—		2		—		16
Interest expense	3		4		11		12
SDG&E:
Revenues	$	5	$	4	$	15	$	12
Cost of sales	25		17		82		67
SoCalGas:
Revenues	$	29	$	24	$	91	$	73
Cost of sales(1)	2		(1)		37		(5)

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

Other Income and Expense Table

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


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Three months ended September 30,				Nine months ended September 30,
	2023		2022		2023		2022
Sempra:
Allowance for equity funds used during construction	$	35	$	35	$	105	$	104
Investment losses, net(1)	(19)		(13)		(2)		(60)
Gains (losses) on interest rate and foreign exchange instruments, net	1		(3)		5		2
Foreign currency transaction (losses) gains, net(2)	(3)		4		1		(18)
Non-service components of net periodic benefit cost	(28)		(77)		(79)		(45)
Interest on regulatory balancing accounts, net	19		7		56		12
Sundry, net	(2)		7		(11)		2
Total	$	3	$	(40)	$	75	$	(3)
SDG&E:
Allowance for equity funds used during construction	$	21	$	22	$	67	$	64
Non-service components of net periodic benefit cost	(5)		(17)		(14)		(8)
Interest on regulatory balancing accounts, net	10		5		31		9
Sundry, net	(1)		2		(9)		3
Total	$	25	$	12	$	75	$	68
SoCalGas:
Allowance for equity funds used during construction	$	14	$	14	$	38	$	40
Non-service components of net periodic benefit cost	(22)		(58)		(60)		(32)
Interest on regulatory balancing accounts, net	9		2		25		3
Sundry, net	(3)		(1)		(12)		(16)
Total	$	(2)	$	(43)	$	(9)	$	(5)

Income Tax Expense and Effective Income Tax Rates Table

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 September 30,						Nine months ended September 30,
	2023			2022			2023			2022
Sempra:
Income tax (benefit) expense	$	(52)		$	21		$	499		$	435

Income before income taxes and equity earnings	$	323		$	165		$	2,175		$	1,194
Equity earnings, before income tax(1)	133			134			418			436
Pretax income	$	456		$	299		$	2,593		$	1,630

Effective income tax rate	(11)		%	7		%	19		%	27		%
SDG&E:
Income tax (benefit) expense	$	(15)		$	35		$	(4)		$	141
Income before income taxes	$	259		$	306		$	712		$	822
Effective income tax rate	(6)		%	11		%	(1)		%	17		%
SoCalGas:
Income tax (benefit) expense	$	(5)		$	(28)		$	68		$	75
Income (loss) before income taxes	$	11		$	(110)		$	600		$	415
Effective income tax rate	(45)		%	25		%	11		%	18		%

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

GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares, basic	$ 721	$ 485	$ 2,293	$ 1,656
Earnings attributable to common shares, diluted	$ 721	$ 485	$ 2,293	$ 1,656
Weighted-average common shares outstanding for basic EPS (in shares)	630,036,000	629,447,000	629,963,000	630,603,000
Dilutive effect of stock options and RSUs (in shares)	2,288,000	2,728,000	2,268,000	2,311,000
Weighted-average common shares outstanding for diluted EPS (in shares)	632,324,000	632,175,000	632,231,000	632,914,000
Earnings per share, basic (dollars per share)	$ 1.14	$ 0.77	$ 3.64	$ 2.63
Earnings per share, diluted (in dollars per share)	$ 1.14	$ 0.77	$ 3.63	$ 2.62
Vested RSUs included in basic WASO (in shares)	716,000	803,000	716,000	805,000
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)			326,574
Performance-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			661,620
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			272,729
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	624,242	0	470,804	230,752

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pension
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 25	$ 27	$ 82	$ 110
Interest cost	39	29	118	88
Expected return on assets	(42)	(46)	(127)	(137)
Amortization of:
Prior service cost (credit)	2	3	4	8
Actuarial loss (gain)	3	8	7	19
Net periodic benefit cost (credit)	27	21	84	88
Regulatory adjustments	30	87	88	84
Total expense (income) recognized	57	108	172	172
Pension \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	8	8	24	28
Interest cost	10	7	30	20
Expected return on assets	(9)	(13)	(29)	(35)
Amortization of:
Actuarial loss (gain)	2	0	4	1
Net periodic benefit cost (credit)	11	2	29	14
Regulatory adjustments	3	24	11	26
Total expense (income) recognized	14	26	40	40
Pension \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	15	16	49	72
Interest cost	24	20	75	61
Expected return on assets	(29)	(30)	(89)	(94)
Amortization of:
Prior service cost (credit)	1	2	3	6
Actuarial loss (gain)	1	6	1	14
Net periodic benefit cost (credit)	12	14	39	59
Regulatory adjustments	27	63	77	58
Total expense (income) recognized	39	77	116	117
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	4	10	17
Interest cost	9	7	28	21
Expected return on assets	(17)	(16)	(52)	(48)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(5)	(4)	(17)	(11)
Net periodic benefit cost (credit)	(11)	(10)	(33)	(23)
Regulatory adjustments	10	10	32	23
Total expense (income) recognized	(1)	0	(1)	0
PBOP \| San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1	2	4
Interest cost	2	1	6	4
Expected return on assets	(2)	(2)	(6)	(7)
Amortization of:
Actuarial loss (gain)	0	(1)	(1)	(2)
Net periodic benefit cost (credit)	1	(1)	1	(1)
Regulatory adjustments	(1)	1	(1)	1
Total expense (income) recognized	0	0	0	0
PBOP \| Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	3	7	13
Interest cost	7	5	21	16
Expected return on assets	(14)	(13)	(44)	(40)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(5)	(3)	(15)	(9)
Net periodic benefit cost (credit)	(11)	(9)	(33)	(22)
Regulatory adjustments	11	9	33	22
Total expense (income) recognized	$ 0	$ 0	$ 0	$ 0

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		9 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) projectOwner bank	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 668	$ 643
Oncor Holdings \| Oncor Electric Delivery Company LLC.
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			80.25%
Sempra Texas Intermediate Holding Company LLC \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			100.00%
Sempra Texas Utilities \| Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Investments made during period			$ 270	256
Proceeds from distributions received			$ 323	255
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity (in percentage)			50.20%
Sempra Infrastructure \| TAG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			$ 36	32
Sempra Infrastructure \| IMG
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received			6
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			18
Sempra Infrastructure \| Other current assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			7
Sempra Infrastructure \| Other long-term assets \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			11
Sempra Infrastructure \| Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Investments made during period			11	19
Proceeds from distributions received			339	$ 388
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Liability cap, amount			$ 979
Number of project owners \| projectOwner		4
Proceeds from related party debt		$ 1,500
Number of project owners sending direct proceeds \| projectOwner		2
Number of project owners sending proceeds from external lenders \| projectOwner		2
Liability cap (as a percent)			130.00%
Sempra Infrastructure \| Cameron LNG JV \| Corporate Joint Venture \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related party debt		$ 753
Return on investments		$ 753
Number of banks \| bank		8
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture
Schedule of Equity Method Investments [Line Items]
Proceeds from distributions received	$ 165
Liability cap, amount	165
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Deferred Credits and Other
Schedule of Equity Method Investments [Line Items]
Senior note, liability	$ 22
Sempra Infrastructure \| Cameron LNG JV \| Promissory Note for SDSRA Distribution \| Corporate Joint Venture \| Other current liabilities
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 19

DEBT AND CREDIT FACILITIES - UNCOMMITTED LETTERS OF CREDIT (Details) $ in Millions	Sep. 30, 2023 USD ($)
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 508
Letters of credit outstanding
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	508
Letters of credit outstanding \| San Diego Gas and Electric Company
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	15
Letters of credit outstanding \| Southern California Gas Company
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	20
Letters of credit outstanding \| Sempra Infrastructure
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	307
Letters of credit outstanding \| Parent and Other
Line of Credit Facility [Line Items]
Uncommitted letters of credit outstanding	$ 166

COMMITMENTS AND CONTINGENCIES (Tables)

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Schedule of Operating Lease Payments Received, Lease Income Table

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


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

Interest income	$	2	$	2	$	5	$	6
Total revenues from sales-type leases(1)	$	2	$	2	$	5	$	6

Operating leases:
Fixed lease payments	$	78	$	71	$	234	$	211
Variable lease payments	10		3		26		7
Total revenues from operating leases(1)	$	88	$	74	$	260	$	218

Depreciation expense	$	15	$	14	$	45	$	41

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

Sales-type Lease, Lease Income

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


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

Interest income	$	2	$	2	$	5	$	6
Total revenues from sales-type leases(1)	$	2	$	2	$	5	$	6

Operating leases:
Fixed lease payments	$	78	$	71	$	234	$	211
Variable lease payments	10		3		26		7
Total revenues from operating leases(1)	$	88	$	74	$	260	$	218

Depreciation expense	$	15	$	14	$	45	$	41

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

NEW ACCOUNTING STANDARDS	9 Months Ended
NEW ACCOUNTING STANDARDS	Sep. 30, 2023
Accounting Changes and Error Corrections [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDSThere are no recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows and/or disclosures.

- Definition

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.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(i)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480016/944-40-65-2

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(ii)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480016/944-40-65-2

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iii)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480016/944-40-65-2

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iv)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480016/944-40-65-2

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Subparagraph (h)(2)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480016/944-40-65-2

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 5
-Subparagraph (SAB Topic 11.M.Q2)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147480530/250-10-S99-5

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (b)(4)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483443/250-10-50-1

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 6
-Subparagraph (i)(1)
-Publisher FASB
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+ Details

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	9 Months Ended
	Sep. 30, 2023 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

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

Sep. 30, 2023

Dec. 31, 2022

Current assets:

Cash and cash equivalents

$ 1,149

$ 370

^[1]

Restricted cash

238

^[1]

Accounts receivable – trade, net

1,939

2,635

^[1]

Accounts receivable – other, net

498

685

^[1]

Due from unconsolidated affiliates

^[1]

Income taxes receivable

113

^[1]

Inventories

451

403

^[1]

Prepaid expenses

325

268

^[1]

Regulatory assets

190

351

^[1]

Fixed-price contracts and other derivatives

201

803

^[1]

Greenhouse gas allowances

144

141

^[1]

Other current assets

^[1]

Total current assets

5,310

5,912

^[1]

Other assets:

Restricted cash

104

^[1]

Regulatory assets

3,277

2,588

^[1]

Greenhouse gas allowances

1,219

796

^[1]

Nuclear decommissioning trusts

827

841

^[1]

Dedicated assets in support of certain benefit plans

513

505

^[1]

Deferred income taxes

155

135

^[1]

Right-of-use assets – operating leases

721

655

^[1]

Investment in Oncor Holdings

14,148

13,665

^[1]

Other investments

2,208

2,012

^[1]

Goodwill

1,602

^[1]

Other intangible assets

324

344

^[1]

Wildfire fund

281

303

^[1]

Other long-term assets

1,874

1,382

^[1]

Total other assets

27,253

24,880

^[1]

Property, plant and equipment:

Property, plant and equipment

70,348

63,893

^[1]

Less accumulated depreciation and amortization

(17,176)

(16,111)

^[1]

Property, plant and equipment, net

53,172

47,782

^[1]

Total assets

85,735

78,574

^[1]

Current liabilities:

Short-term debt

1,977

3,352

^[1]

Accounts payable – trade

2,234

1,994

^[1]

Accounts payable – other

219

275

^[1]

Dividends and interest payable

734

621

^[1]

Accrued compensation and benefits

496

484

^[1]

Regulatory liabilities

529

504

^[1]

Current portion of long-term debt and finance leases

974

1,019

^[1]

Reserve for Aliso Canyon costs

126

129

^[1]

Greenhouse gas obligations

144

141

^[1]

Total current liabilities

8,765

9,899

^[1]

Long-term debt and finance leases

27,703

24,548

^[1]

Deferred credits and other liabilities:

Due to unconsolidated affiliates

303

301

^[1]

Regulatory liabilities

3,468

3,341

^[1]

Greenhouse gas obligations

942

565

^[1]

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

309

410

^[1]

Deferred income taxes

5,095

4,591

^[1]

Asset retirement obligations

3,584

3,546

^[1]

Deferred credits and other

2,308

2,117

^[1]

Total deferred credits and other liabilities

16,009

14,871

^[1]

Commitments and contingencies

^[1]

Equity:

Common stock

12,038

12,160

^[1]

Retained earnings

15,371

14,201

^[1]

Accumulated other comprehensive income (loss)

(60)

(135)

^[1]

Total shareholders’ equity

28,238

27,115

^[1]

Preferred stock of subsidiary

^[1]

Other noncontrolling interests

5,000

2,121

^[1]

Total equity

33,258

29,256

^[1]

Total liabilities and equity

85,735

78,574

^[1]

Related Party

Current assets:

Due from unconsolidated affiliates

Current liabilities:

Other current liabilities

^[1]

Nonrelated Party

Current liabilities:

Other current liabilities

1,327

1,380

^[1]

Series C Preferred Stock

Equity:

Preferred stock

$ 889

^[1]

[1]	Derived from audited financial statements.

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Commodity Derivative Volumes Table

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES

(Quantities in millions)

Commodity

Unit of measure

September 30, 2023

December 31, 2022

Sempra:

Natural gas

MMBtu

441

254

Electricity

MWh

—

Congestion revenue rights

MWh

SDG&E:

Natural gas

MMBtu

Congestion revenue rights

MWh

SoCalGas:

Natural gas

MMBtu

347

224

Notional Amounts of Derivatives Table

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

INTEREST RATE DERIVATIVES

(Dollars in millions)

September 30, 2023

December 31, 2022

Notional debt

Maturities

Notional debt

Maturities

Sempra:

Cash flow hedges(1)

4,454

2023-2048

294

2023-2034

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

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


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	September 30, 2023			December 31, 2022
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	—	—	$	306	2023
Other foreign currency derivatives	150		2023-2025	111		2023-2024

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)
	September 30, 2023
	Current assets: Fixed-price contracts and other derivatives(1)		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	15	$	363	$	—	$	—
Foreign exchange instruments	—		1		(8)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	175		25		(172)		(29)
Associated offsetting commodity contracts	(166)		(22)		166		22
Commodity contracts subject to rate recovery	22		15		(171)		(6)
Associated offsetting commodity contracts	(16)		(3)		16		3
Associated offsetting cash collateral	—		—		—		1
Net amounts presented on the balance sheet	30		379		(169)		(9)
Additional cash collateral for commodity contracts not subject to rate recovery	89		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	82		—		—		—
Total(2)	$	201	$	379	$	(169)	$	(9)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	18	$	15	$	(13)	$	(4)
Associated offsetting commodity contracts	(12)		(3)		12		3
Associated offsetting cash collateral	—		—		—		1
Net amounts presented on the balance sheet	6		12		(1)		—
Additional cash collateral for commodity contracts subject to rate recovery	80		—		—		—
Total(2)	$	86	$	12	$	(1)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4	$	—	$	(158)	$	(2)
Associated offsetting commodity contracts	(4)		—		4		—
Net amounts presented on the balance sheet	—		—		(154)		(2)
Additional cash collateral for commodity contracts subject to rate recovery	2		—		—		—
Total	$	2	$	—	$	(154)	$	(2)

(1) Included in Other Current Assets for SoCalGas.

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


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

(1) Included in Other Current Assets for SoCalGas.

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

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

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


CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended September 30,					Three months ended September 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	320	$	4	Interest Expense	$	(1)	$	(2)
Interest rate instruments	32		68		Equity Earnings(1)	12		(1)
Foreign exchange instruments	8		2		Revenues: Energy- Related Businesses	—		—
					Other Income (Expense), Net	1		—
Foreign exchange instruments	7		1		Equity Earnings(1)	1		—
Interest rate and foreign exchange instruments	—		—		Other Income (Expense), Net	—		(3)
Total	$	367	$	75		$	13	$	(6)



	Nine months ended September 30,					Nine months ended September 30,
	2023		2022		Location	2023		2022
Sempra:
Interest rate instruments	$	337	$	39	Interest Expense	$	(1)	$	(1)
Interest rate instruments	56		212		Equity Earnings(1)	33		(28)
Foreign exchange instruments	—		(1)		Revenues: Energy- Related Businesses	—		2
					Other Income (Expense), Net	(1)		(1)
Foreign exchange instruments	1		(1)		Equity Earnings(1)	(1)		1
Interest rate and foreign exchange instruments	7		13		Interest Expense	1		1
					Other Income (Expense), Net	6		3
Total	$	401	$	262		$	37	$	(23)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	(1)

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

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

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


UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax gain (loss) on derivatives recognized in earnings
		Three months ended September 30,				Nine months ended September 30,
	Location	2023		2022		2023		2022
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	83	$	(227)	$	785	$	(455)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(125)		(11)		(172)		(15)
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	23		16		5		10
Interest rate instrument	Interest Expense	—		—		(47)		—
Total		$	(19)	$	(222)	$	571	$	(460)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	23	$	16	$	5	$	10
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(125)	$	(11)	$	(172)	$	(15)

- Definition

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.

+ References + Details

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Sep. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.86%	5.57%
San Diego Gas and Electric Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.00%	4.76%
Southern California Gas Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	5.37%	4.71%

- Definition

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.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 835
-SubTopic 30
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482900/835-30-50-1

Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(f))
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
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+ Details

COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION NARRATIVE (Details) - San Diego Gas and Electric Company $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($) agreement
Lessee, Lease, Description [Line Items]
Right-of-use asset and lease liability	$ 101
Undiscounted lease payments due remainder of the year	9
Undiscounted lease payments due year two	13
Undiscounted lease payments due year three	13
Undiscounted lease payments due year one	13
Undiscounted lease payments due year four	13
Undiscounted lease payments due thereafter	$ 66
Purchased-Power Contracts
Lessee, Lease, Description [Line Items]
Number of purchased-power contracts \| agreement	7
Lease not yet commenced, year one	$ 32
Lease not yet commenced, year two	61
Lease not yet commenced, year three	82
Lease not yet commenced, year four	83
Lease not yet commenced, thereafter	$ 919

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

Total

Common stock

Retained earnings

Accumulated other comprehensive income (loss)

San Diego Gas and Electric Company

Common stock

San Diego Gas and Electric Company

Retained earnings

San Diego Gas and Electric Company

Accumulated other comprehensive income (loss)

Beginning Balance at Dec. 31, 2021

$ 27,419

$ 11,862

$ 13,548

$ (318)

$ 8,249

$ 1,660

$ 6,599

$ (10)

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

Net income

1,877

1,690

681

Other comprehensive (loss) income

245

189

Common stock dividends declared

(1,081)

(100)

Ending balance at Sep. 30, 2022

29,289

12,138

14,123

(120)

8,831

1,660

7,180

(9)

Beginning Balance at Jun. 30, 2022

29,053

12,121

13,998

(167)

8,659

1,660

7,009

(10)

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

Net income

561

496

271

Other comprehensive (loss) income

Common stock dividends declared

(360)

(100)

Ending balance at Sep. 30, 2022

29,289

12,138

14,123

(120)

8,831

1,660

7,180

(9)

Beginning Balance at Dec. 31, 2022

29,256

^[1]

12,160

14,201

(135)

9,067

1,660

7,414

(7)

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

Net income

2,762

2,327

716

Other comprehensive (loss) income

333

121

Common stock dividends declared

(1,123)

(100)

Ending balance at Sep. 30, 2023

33,258

12,038

15,371

(60)

9,683

1,660

8,030

(7)

Beginning Balance at Jun. 30, 2023

31,014

12,044

15,024

(121)

9,509

1,660

7,856

(7)

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

Net income

854

732

274

Other comprehensive (loss) income

309

107

Common stock dividends declared

(374)

(100)

Ending balance at Sep. 30, 2023

$ 33,258

$ 12,038

$ 15,371

$ (60)

$ 9,683

$ 1,660

$ 8,030

$ (7)

[1]	Derived from audited financial statements.

- Definition

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

+ References

+ Details

- Definition

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

+ References

+ Details

- Definition

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

+ References

+ Details

DERIVATIVE FINANCIAL INSTRUMENTS - INTEREST RATE DERIVATIVES (Details) $ in Millions	1 Months Ended	9 Months Ended
	Mar. 31, 2023 USD ($) counterparty	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Derivative [Line Items]
Cash paid to settle		$ 99	$ 0
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG \| Secured Overnight Financing Rate (SOFR)
Derivative [Line Items]
Minimum amount of the projected amount of term loans (in percent)	60.00%
Loan Agreement To Finance The Cost Of Development And Construction Of The PA LNG Phase 1 Project \| Port Arthur LNG \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Derivative [Line Items]
Minimum amount of the projected amount of term loans (in percent)	60.00%
Interest Rate Swap \| Cash Flow Hedging
Derivative [Line Items]
Amount of interest rate swap				$ 3,500
Interest rate swap tenor (in years)		25 years
Notional amounts		$ 491		$ 294
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG
Derivative [Line Items]
Cash paid to settle	$ 14
Number of counterparties \| counterparty	17
Fixed rate (in percent)		3.23%
Interest Rate Swap \| Cash Flow Hedging \| Port Arthur LNG \| Maximum
Derivative [Line Items]
Notional amounts		$ 4,200

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	9 Months Ended
GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	Sep. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Effective May 12, 2023, our company changed its legal name from Sempra Energy to Sempra. Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra, a California-based holding company, and its consolidated entities. We have four separate reportable segments, which we discuss in Note 11. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra. SoCalGas SoCalGas’ common stock is wholly owned by Pacific Enterprises, which is a wholly owned subsidiary of Sempra.
Basis of Presentation	BASIS OF PRESENTATION This is a combined report of Sempra, SDG&E and SoCalGas. We provide separate information for SDG&E and SoCalGas as required. We have eliminated intercompany accounts and transactions within Sempra’s consolidated financial statements. We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after September 30, 2023 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. All December 31, 2022 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2022 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. We follow the same accounting policies for interim period reporting purposes. The information contained in this report should be read in conjunction with the Annual Report.
Regulated Operations	Regulated Operations SDG&E, SoCalGas and Sempra Infrastructure’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss revenue recognition and the effects of regulation at our utilities in Notes 3 and 4 below and in Notes 1, 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas. Certain business activities at Sempra Infrastructure are regulated by the CRE and the FERC and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.
Credit Losses	We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in sales-type leases and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 5. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered.
Variable Interest Entity	VARIABLE INTEREST ENTITIES We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess: ▪the purpose and design of the VIE; ▪the nature of the VIE’s risks and the risks we absorb; ▪the power to direct activities that most significantly impact the economic performance of the VIE; and ▪the obligation to absorb losses or the right to receive benefits that could be significant to the VIE. We will continue to evaluate our VIEs for any changes that may impact our determination of whether an entity is a VIE and if we are the primary beneficiary.
Earnings Per Share	Basic EPS is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect.
Interim Period Effective Tax Rate	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, beginning in 2023, the scope of projects eligible for investment tax credits was expanded to include standalone energy storage projects. The IRA also provided an election that prospectively permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the applicable asset. Under this election, SDG&E recorded a regulatory liability to offset these investment tax credits, which reduced SDG&E’s and Sempra’s ETR in 2023. In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting for gas repairs expenditures. As a result of this Revenue Procedure, SoCalGas updated its assessment of prior years’ unrecognized income tax benefits and, in the nine months ended September 30, 2023, recorded an income tax benefit of $43 million for previously unrecognized income tax benefits pertaining to gas repairs expenditures. SoCalGas recorded an associated regulatory liability for the portion that will benefit customers in the future. We are assessing the potential future impacts of this Revenue Procedure.In the nine months ended September 30, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested.
Derivative Financial Instruments	HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk of variability of future cash flows of a given revenue or expense item, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risk, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans limited by company policy. SDG&E’s risk management and transacting activity plans for electricity derivatives are also required to be filed with, and have been approved by, the CPUC. SoCalGas is also subject to certain regulatory requirements and thresholds related to natural gas procurement under the GCIM. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Natural Gas or in Cost of Electric Fuel and Purchased Power. ▪SDG&E is allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. ▪Sempra Infrastructure may use natural gas and electricity derivatives, as appropriate, in an effort to optimize the earnings of its assets which support the following businesses: LNG, natural gas pipelines and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues on the Condensed Consolidated Statements of Operations. ▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other derivatives to hedge exposures such as GHG allowances. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock in interest rates on outstanding debt or in anticipation of future financings. In December 2022, Sempra Infrastructure entered into an undesignated contingent interest rate swap to lock in interest rates on up to $3.5 billion of the variable rate indebtedness from anticipated future project-level debt financing that would be used to pay for construction costs of the PA LNG Phase 1 project. The contingent interest rate swap had a 25-year tenor, and its settlement was conditional upon the closing of project-level debt financing with respect to the PA LNG Phase 1 project. In March 2023, we closed on the project-level debt financing and, shortly thereafter, paid $14 million to cash settle the contingent interest rate swap. As we discuss in Note 6, a minimum of 60% of the projected amount of term loans outstanding is required to be hedged under the Port Arthur LNG term loan facility agreement. In March 2023, Port Arthur LNG entered into floating-to-fixed interest rate swaps with 17 counterparties to hedge the variability in cash flows related to the SOFR-based component of interest payments on forecasted loans outstanding under the agreement. The notional amounts of the interest rate swaps generally increase in proportion to the forecasted borrowings up to a maximum amount of $4.2 billion prior to the maturity of the term loans on March 20, 2030. Under the interest rate swaps, which are designated as cash flow hedges, Port Arthur LNG receives interest at Term SOFR and pays interest at a fixed rate of 3.23% based on amortizing notional amounts maturing in 2048. FOREIGN CURRENCY DERIVATIVES We may utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. These cash flow hedges exchange our Mexican peso-denominated principal and interest payments into the U.S. dollar and swap Mexican fixed interest rates for U.S. fixed interest rates. From time to time, Sempra Infrastructure and its JVs may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. We are also exposed to exchange rate movements at our Mexican subsidiaries and JVs, which have U.S. dollar-denominated cash balances, receivables, payables and debt (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We may utilize foreign currency derivatives as a means to manage the risk of exposure to significant fluctuations in our income tax expense and equity earnings from these impacts; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. CREDIT RISK RELATED CONTINGENT FEATURES For Sempra, SDG&E and SoCalGas, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. For Sempra, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.
Fair Value Measurement	We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2022. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following: ▪Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪For commodity contracts, interest rate instruments and foreign exchange instruments, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below in “Level 3 Information – SDG&E.” ▪Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1). ▪As we discuss in Note 5, in July 2020, Sempra entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra Infrastructure.” CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following yearRealized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings.Fair Value of Financial InstrumentsThe fair values of certain of our financial instruments (cash, accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts.
Gains and Losses on NDTs	Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Legal Proceedings	LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.
Segment Information	We have four separately managed reportable segments, as follows: ▪SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electricity transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, L.L.C., a regulated electric transmission utility serving customers near the Texas-Mexico border. ▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. We evaluate each segment’s performance based on its contribution to Sempra’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, the FERC. The cost of common services shared by the business segments is assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (52)	$ 21	$ 499	$ 435
Income before income taxes and equity earnings	323	165	2,175	1,194
Equity earnings, before income tax:	133	134	418	436
Pretax income	$ 456	$ 299	$ 2,593	$ 1,630
Effective income tax rate (as a percent)	(11.00%)	7.00%	19.00%	27.00%
San Diego Gas and Electric Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (15)	$ 35	$ (4)	$ 141
Income before income taxes and equity earnings	$ 259	$ 306	$ 712	$ 822
Effective income tax rate (as a percent)	(6.00%)	11.00%	(1.00%)	17.00%
Southern California Gas Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ (5)	$ (28)	$ 68	$ 75
Income before income taxes and equity earnings	$ 11	$ (110)	$ 600	$ 415
Effective income tax rate (as a percent)	(45.00%)	25.00%	11.00%	18.00%

- Definition

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.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 944
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04(11))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483586/944-220-S99-1

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 22
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-22

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 30
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-30

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 32
-Subparagraph (f)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-32

Reference 5: http://www.xbrl.org/2003/role/exampleRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 31
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-31

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 32
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147482810/280-10-50-32

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 942
-SubTopic 235
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-05(b)(2))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147479557/942-235-S99-1

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Name Accounting Standards Codification
-Section 25
-Paragraph 1
-SubTopic 20
-Topic 940
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147481913/940-20-25-1

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(10))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483621/220-10-S99-2

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Topic 942
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(15))
-Publisher FASB
-URI https://asc.fasb.org//1943274/2147483589/942-220-S99-1

+ Details

- Definition

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

+ References + Details

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PROPERTY, PLANT AND EQUIPMENT (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($) segment
Property, Plant and Equipment [Line Items]
Number of reportable segments	4
Sempra Infrastructure
Property, Plant and Equipment [Line Items]
Number of reportable segments	2
Sempra Infrastructure \| Guaymas-El Oro segment of the Sonora Pipeline
Property, Plant and Equipment [Line Items]
Property, plant and equipment \| $	$ 411

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 315	$ 66	$ 321	$ 227
Pretax gain (loss) on derivatives recognized in earnings	1	(3)	5	2
Derivatives designated as hedging instruments: \| Cash Flow Hedging
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	367	75	401	262
Pretax gain (loss) reclassified from AOCI into earnings	13	(6)	37	(23)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	320	4	337	39
Pretax gain (loss) reclassified from AOCI into earnings	(1)	(2)	(1)	(1)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate instruments \| Southern California Gas Company
Derivative [Line Items]
Pretax gain (loss) recognized in OCI			0	0
Pretax gain (loss) reclassified from AOCI into earnings			(1)	(1)
Derivatives designated as hedging instruments: \| Interest Expense \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI			7	13
Pretax gain (loss) reclassified from AOCI into earnings			1	1
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Interest rate instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	32	68	56	212
Pretax gain (loss) reclassified from AOCI into earnings	12	(1)	33	(28)
Derivatives designated as hedging instruments: \| Equity Earnings \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	7	1	1	(1)
Pretax gain (loss) reclassified from AOCI into earnings	1	0	(1)	1
Derivatives designated as hedging instruments: \| Revenues: Energy- Related Businesses \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	8	2	0	(1)
Pretax gain (loss) reclassified from AOCI into earnings	0	0	0	2
Derivatives designated as hedging instruments: \| Other Income (Expense), Net \| Cash Flow Hedging \| Foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	1	0	(1)	(1)
Derivatives designated as hedging instruments: \| Other Income (Expense), Net \| Cash Flow Hedging \| Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	0
Pretax gain (loss) reclassified from AOCI into earnings	0	(3)	6	3
Derivatives not designated as hedging instruments:
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(19)	(222)	571	(460)
Derivatives not designated as hedging instruments: \| Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	83	(227)	785	(455)
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| Southern California Gas Company
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(125)	(11)	(172)	(15)
Derivatives not designated as hedging instruments: \| Commodity contracts subject to rate recovery \| San Diego Gas and Electric Company
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	23	16	5	10
Derivatives not designated as hedging instruments: \| Contingent Interest Rate Derivative
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	(47)	0
Derivatives not designated as hedging instruments: \| Cost of Electric Fuel and Purchased Power \| Commodity contracts subject to rate recovery
Derivative [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	23	16	5	10
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	$ (125)	$ (11)	$ (172)	$ (15)

REGULATORY MATTERS - COST OF CAPITAL & FERC (Details) - California Public Utilities Commission - Forecast	24 Months Ended	36 Months Ended
	Dec. 31, 2025	Dec. 31, 2025
San Diego Gas and Electric Company
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)	100.00%	100.00%
Weighted return on rate base (as a percent)	7.67%	7.18%
San Diego Gas and Electric Company \| Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	45.25%	45.25%
San Diego Gas and Electric Company \| Authorized Weighting \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	2.75%	2.75%
San Diego Gas and Electric Company \| Authorized Weighting \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	52.00%	52.00%
San Diego Gas and Electric Company \| Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	4.34%	4.05%
San Diego Gas and Electric Company \| Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	6.22%	6.22%
San Diego Gas and Electric Company \| Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	10.65%	9.95%
San Diego Gas and Electric Company \| Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	1.96%	1.83%
San Diego Gas and Electric Company \| Weighted Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.17%	0.17%
San Diego Gas and Electric Company \| Weighted Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	5.54%	5.17%
Southern California Gas Company
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)	100.00%	100.00%
Weighted return on rate base (as a percent)	7.67%	7.10%
Southern California Gas Company \| Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	45.60%	45.60%
Southern California Gas Company \| Authorized Weighting \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	2.40%	2.40%
Southern California Gas Company \| Authorized Weighting \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	52.00%	52.00%
Southern California Gas Company \| Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	4.54%	4.07%
Southern California Gas Company \| Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	6.00%	6.00%
Southern California Gas Company \| Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	10.50%	9.80%
Southern California Gas Company \| Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	2.07%	1.86%
Southern California Gas Company \| Weighted Return on Rate Base \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.14%	0.14%
Southern California Gas Company \| Weighted Return on Rate Base \| Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	5.46%	5.10%

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 30	$ 333
Additional cash collateral for commodity contracts not subject to rate recovery	89	451
Additional cash collateral for commodity contracts subject to rate recovery	82	18
Total	201	802
Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	379	152
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	379	152
Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(169)	(280)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(169)	(280)
Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(9)	(94)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(9)	(94)
Derivatives designated as hedging instruments: \| Other current assets
Derivatives designated as hedging instruments:
Interest rate instruments	15	10
Foreign exchange instruments	0	0
Interest rate and foreign exchange instruments		0
Derivatives designated as hedging instruments: \| Other long-term assets
Derivatives designated as hedging instruments:
Interest rate instruments	363	33
Foreign exchange instruments	1	0
Interest rate and foreign exchange instruments		0
Derivatives designated as hedging instruments: \| Other current liabilities
Derivatives designated as hedging instruments:
Interest rate instruments	0	0
Foreign exchange instruments	(8)	(7)
Interest rate and foreign exchange instruments		(105)
Derivatives designated as hedging instruments: \| Deferred credits and other
Derivatives designated as hedging instruments:
Interest rate instruments	0	0
Foreign exchange instruments	0	(1)
Interest rate and foreign exchange instruments		0
Derivatives not designated as hedging instruments: \| Other current assets
Derivatives designated as hedging instruments:
Interest rate instruments		33
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	175	480
Associated offsetting commodity contracts	(166)	(301)
Commodity contracts subject to rate recovery	22	138
Associated offsetting commodity contracts	(16)	(27)
Associated offsetting cash collateral	0
Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	25	133
Associated offsetting commodity contracts	(22)	(39)
Commodity contracts subject to rate recovery	15	27
Associated offsetting commodity contracts	(3)	(2)
Associated offsetting cash collateral	0
Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(172)	(399)
Associated offsetting commodity contracts	166	301
Commodity contracts subject to rate recovery	(171)	(97)
Associated offsetting commodity contracts	16	27
Associated offsetting cash collateral	0
Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives designated as hedging instruments:
Interest rate instruments		0
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(29)	(132)
Associated offsetting commodity contracts	22	39
Commodity contracts subject to rate recovery	(6)	(2)
Associated offsetting commodity contracts	3	2
Associated offsetting cash collateral	1
San Diego Gas and Electric Company \| Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	6	95
Additional cash collateral for commodity contracts subject to rate recovery	80	17
Total	86	112
San Diego Gas and Electric Company \| Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	12	25
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	12	25
San Diego Gas and Electric Company \| Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(1)	(1)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(1)	(1)
San Diego Gas and Electric Company \| Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other current assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	18	107
Associated offsetting commodity contracts	(12)	(12)
Associated offsetting cash collateral	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	15	27
Associated offsetting commodity contracts	(3)	(2)
Associated offsetting cash collateral	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(13)	(13)
Associated offsetting commodity contracts	12	12
Associated offsetting cash collateral	0
San Diego Gas and Electric Company \| Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(4)	(2)
Associated offsetting commodity contracts	3	2
Associated offsetting cash collateral	1
Southern California Gas Company \| Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	16
Additional cash collateral for commodity contracts subject to rate recovery	2	1
Total	2	17
Southern California Gas Company \| Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
Southern California Gas Company \| Other current liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(154)	(69)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(154)	(69)
Southern California Gas Company \| Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(2)	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(2)	0
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other current assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	4	31
Associated offsetting commodity contracts	(4)	(15)
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other long-term assets
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	0	0
Associated offsetting commodity contracts	0	0
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Other current liabilities
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(158)	(84)
Associated offsetting commodity contracts	4	15
Southern California Gas Company \| Derivatives not designated as hedging instruments: \| Deferred credits and other
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(2)	0
Associated offsetting commodity contracts	$ 0	$ 0

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Sep. 30, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 5,530
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 85
Revenues to be recognized, period of recognition	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 300
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 338
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 365
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 365
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,077
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 76
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 1
Revenues to be recognized, period of recognition	3 months
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 59
Revenues to be recognized, period of recognition