10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549 

FORM 10-Q

(Mark One)
☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended		June 30, 2022
		or
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from			to

Commission File No.	Exact Name of Registrant as Specified in its Charter, Address of Principal Executive Office and Telephone Number		State of Incorporation	I.R.S. Employer Identification No.	Former name, former address and former fiscal year, if changed since last report
1-14201	SEMPRA ENERGY		California	33-0732627	No change
	488 8th Avenue
	San Diego, California 92101
	(619) 696-2000
1-03779	SAN DIEGO GAS & ELECTRIC COMPANY		California	95-1184800	No change
	8326 Century Park Court
	San Diego, California 92123
	(619) 696-2000
1-01402	SOUTHERN CALIFORNIA GAS COMPANY		California	95-1240705	No change
	555 West Fifth Street
	Los Angeles, California 90013
	(213) 244-1200

SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Title of Each Class	Trading Symbol	Name of Each Exchange on Which Registered
SEMPRA ENERGY:
Common Stock, without par value	SRE	New York Stock Exchange
5.75% Junior Subordinated Notes Due 2079, $25 par value	SREA	New York Stock Exchange
SAN DIEGO GAS & ELECTRIC COMPANY:
None
SOUTHERN CALIFORNIA GAS COMPANY:
None

1

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Sempra Energy	Yes	☒	No	☐
San Diego Gas & Electric Company	Yes	☒	No	☐
Southern California Gas Company	Yes	☒	No	☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Sempra Energy	Yes	☒	No	☐
San Diego Gas & Electric Company	Yes	☒	No	☐
Southern California Gas Company	Yes	☒	No	☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Sempra Energy:
☒ Large Accelerated Filer	☐ Accelerated Filer	☐ Non-accelerated Filer	☐ Smaller Reporting Company	☐ Emerging Growth Company
San Diego Gas & Electric Company:
☐ Large Accelerated Filer	☐ Accelerated Filer	☒ Non-accelerated Filer	☐ Smaller Reporting Company	☐ Emerging Growth Company
Southern California Gas Company:
☐ Large Accelerated Filer	☐ Accelerated Filer	☒ Non-accelerated Filer	☐ Smaller Reporting Company	☐ Emerging Growth Company

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Sempra Energy	Yes	☐	No	☐
San Diego Gas & Electric Company	Yes	☐	No	☐
Southern California Gas Company	Yes	☐	No	☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Sempra Energy	Yes	☐	No	☒
San Diego Gas & Electric Company	Yes	☐	No	☒
Southern California Gas Company	Yes	☐	No	☒
Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date.
Common stock outstanding on August 1, 2022:

Sempra Energy	314,310,331 shares
San Diego Gas & Electric Company	Wholly owned by Enova Corporation, which is wholly owned by Sempra Energy
Southern California Gas Company	Wholly owned by Pacific Enterprises, which is wholly owned by Sempra Energy

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TABLE OF CONTENTS
		Page
Glossary		4
Information Regarding Forward-Looking Statements		7
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements	9
	Notes to Condensed Consolidated Financial Statements
	Note 1. General Information and Other Financial Data	29
	Note 2. New Accounting Standards	47
	Note 3. Revenues	48
	Note 4. Regulatory Matters	51
	Note 5. Acquisitions and Divestitures	53
	Note 6. Investments in Unconsolidated Entities	54
	Note 7. Debt and Credit Facilities	56
	Note 8. Derivative Financial Instruments	58
	Note 9. Fair Value Measurements	64
	Note 10. San Onofre Nuclear Generating Station	72
	Note 11. Commitments and Contingencies	74
	Note 12. Segment Information	83
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	86
	Overview	86
	Results of Operations	87
	Capital Resources and Liquidity	98
	Critical Accounting Estimates	111
	New Accounting Standards	111
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	112
Item 4.	Controls and Procedures	113
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	113
Item 1A.	Risk Factors	113
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	114
Item 6.	Exhibits	115
Signatures		118

This combined Form 10-Q is separately filed by Sempra Energy doing business as Sempra, San Diego Gas & Electric Company and Southern California Gas Company. Information contained herein relating to any one of these individual reporting entities is filed by such entity on its own behalf. Each entity makes statements herein only as to itself and its consolidated entities and makes no statement whatsoever as to any other entity.

You should read this report in its entirety as it pertains to each respective reporting entity. No one section of the report deals with all aspects of the subject matter. A separate Part I – Item 1 is provided for each reporting entity, except for the Notes to Condensed Consolidated Financial Statements. The Notes to Condensed Consolidated Financial Statements for all of the reporting entities are combined. All Items other than Part I – Item 1 are combined for the three reporting entities.

None of the website references in this report are active hyperlinks, and the information contained on, or that can be accessed through, any such website is not, and shall not be deemed to be, part of this report.

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The following terms and abbreviations appearing in this report have the meanings indicated below.

GLOSSARY
AB	California Assembly Bill
ADIA	Black Silverback ZC 2022 LP (assignee of Black River B 2017 Inc.), a wholly owned affiliate of Abu Dhabi Investment Authority
AFUDC	allowance for funds used during construction
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2021
AOCI	accumulated other comprehensive income (loss)
ARO	asset retirement obligation
ASC	Accounting Standards Codification
ASEA	Agencia de Seguridad, Energía y Ambiente (Mexico’s National Agency for Industrial Safety and Environmental Protection)
ASR	accelerated share repurchase
ASU	Accounting Standards Update
Bcf	billion cubic feet
Bechtel	Bechtel Oil, Gas and Chemicals, Inc.
Blade	Blade Energy Partners
bps	basis points
CalGEM	California Geologic Energy Management Division
Cameron LNG JV	Cameron LNG Holdings, LLC
CCA	Community Choice Aggregation
CCM	cost of capital adjustment mechanism
CENACE	Centro Nacional de Control de Energía (Mexico’s National Center for Energy Control)
CFE	Comisión Federal de Electricidad (Mexico’s Federal Electricity Commission)
CFIN	Cameron LNG FINCO, LLC, a wholly owned and unconsolidated affiliate of Cameron LNG JV
COVID-19	coronavirus disease 2019
CPUC	California Public Utilities Commission
CRE	Comisión Reguladora de Energía (Mexico’s Energy Regulatory Commission)
CRR	congestion revenue right
DOE	U.S. Department of Energy
ECA LNG	ECA LNG Phase 1 and ECA LNG Phase 2, collectively
ECA LNG Phase 1	ECA LNG Holdings B.V.
ECA LNG Phase 2	ECA LNG II Holdings B.V.
ECA Regas Facility	Energía Costa Azul, S. de R.L. de C.V. LNG regasification facility
Ecogas	Ecogas México, S. de R.L. de C.V.
Edison	Southern California Edison Company, a subsidiary of Edison International
EFH	Energy Future Holdings Corp. (renamed Sempra Texas Holdings Corp.)
EPC	engineering, procurement and construction
EPS	earnings (losses) per common share
ESJ	Energía Sierra Juárez, S. de R.L. de C.V.
ETR	effective income tax rate
FEED	Front-End Engineering Design
FERC	Federal Energy Regulatory Commission
Fitch	Fitch Ratings
FTA	Free Trade Agreement
Gazprom	Gazprom Marketing & Trading México S. de R.L. de C.V.
GRC	General Rate Case
HOA	Heads of Agreement
IEnova	Infraestructura Energética Nova, S.A.P.I. de C.V.
IMG	Infraestructura Marina del Golfo
IOU	investor-owned utility
ISO	Independent System Operator
JV	joint venture

4

GLOSSARY (CONTINUED)
KKR	KKR Pinnacle Investor L.P. (as successor-in-interest to KKR Pinnacle Aggregator L.P.), an affiliate of Kohlberg Kravis Roberts & Co. L.P.
LA Superior Court	Los Angeles County Superior Court
Leak	the leak at the SoCalGas Aliso Canyon natural gas storage facility injection-and-withdrawal well, SS25, discovered by SoCalGas on October 23, 2015
LNG	liquefied natural gas
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
Mexican Stock Exchange	Bolsa Mexicana de Valores, S.A.B. de C.V., or BMV
MMBtu	million British thermal units (of natural gas)
Moody’s	Moody’s Investors Service
MOU	Memorandum of Understanding
Mtpa	million tonnes per annum
MW	megawatt
MWh	megawatt hour
NCI	noncontrolling interest(s)
NDT	nuclear decommissioning trusts
NEIL	Nuclear Electric Insurance Limited
O&M	operation and maintenance expense
OCI	other comprehensive income (loss)
OII	Order Instituting Investigation
Oncor	Oncor Electric Delivery Company LLC
Oncor Holdings	Oncor Electric Delivery Holdings Company LLC
OSC	Order to Show Cause
PA LNG Phase 1 project	initial phase of the proposed Port Arthur LNG liquefaction export project
PA LNG Phase 2 project	second phase of the proposed Port Arthur LNG liquefaction export project
PG&E	Pacific Gas and Electric Company
PGNiG	Polish Oil & Gas Company
PP&E	property, plant and equipment
PPA	power purchase agreement
PUCT	Public Utility Commission of Texas
RBS	The Royal Bank of Scotland plc
RBS SEE	RBS Sempra Energy Europe
RBS Sempra Commodities	RBS Sempra Commodities LLP
ROE	return on equity
RSU	restricted stock unit
S&P	S&P Global Ratings, a division of S&P Global Inc.
Saavi Energía	Saavi Energía S. de R.L. de C.V.
SB	California Senate Bill
SDG&E	San Diego Gas & Electric Company
SDSRA	Senior Debt Service Reserve Account
SEC	U.S. Securities and Exchange Commission
SED	Safety and Enforcement Division of the CPUC
SEDATU	Secretaría de Desarrollo Agrario, Territorial y Urbano (Mexico’s agency in charge of agriculture, land and urban development)
Sempra	Sempra Energy doing business as Sempra, together with its consolidated entities unless otherwise stated or indicated by the context
Sempra California	San Diego Gas & Electric Company and Southern California Gas Company, collectively
SENER	Secretaría de Energía de México (Mexico’s Ministry of Energy)
series A preferred stock	6% mandatory convertible preferred stock, series A
series B preferred stock	6.75% mandatory convertible preferred stock, series B
Shell Mexico	Shell México Gas Natural, S. de R.L. de C.V.
SI Partners	Sempra Infrastructure Partners, LP, the holding company for most of Sempra’s subsidiaries not subject to California or Texas utility regulation

5

GLOSSARY (CONTINUED)
SoCalGas	Southern California Gas Company
SONGS	San Onofre Nuclear Generating Station
SPA	sale and purchase agreement
Support Agreement	support agreement, dated July 28, 2020 and amended on June 29, 2021, among Sempra and Sumitomo Mitsui Banking Corporation
TAG	TAG Norte Holding, S. de R.L. de C.V.
TdM	Termoeléctrica de Mexicali
Technip Energies	TP Oil & Gas Mexico, S. De R.L. De C.V., an affiliate of Technip Energies N.V.
U.S. GAAP	generally accepted accounting principles in the United States of America
VAT	value-added tax
Ventika	Ventika, S.A.P.I. de C.V. and Ventika II, S.A.P.I. de C.V., collectively
VIE	variable interest entity
Wildfire Fund	the fund established pursuant to AB 1054
Wildfire Legislation	AB 1054 and AB 111

References in this report to “we,” “our,” “us,” “our company” and “Sempra” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We sometimes refer to SDG&E and SoCalGas collectively as Sempra California, which does not include the utilities in our Sempra Texas Utilities or Sempra Infrastructure segments. All references in this report to our reportable segments are not intended to refer to any legal entity with the same or similar name.

Throughout this report, we refer to the following as Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements when discussed together or collectively:

•the Condensed Consolidated Financial Statements and related Notes of Sempra;

•the Condensed Financial Statements and related Notes of SDG&E; and

•the Condensed Financial Statements and related Notes of SoCalGas.

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INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

We make statements in this report that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are based on assumptions with respect to the future, involve risks and uncertainties, and are not guarantees. Future results may differ materially from those expressed or implied in any forward-looking statements. These forward-looking statements represent our estimates and assumptions only as of the filing date of this report. We assume no obligation to update or revise any forward-looking statement as a result of new information, future events or other factors.

Forward-looking statements can be identified by words such as “believes,” “expects,” “intends,” “anticipates,” “contemplates,” “plans,” “estimates,” “projects,” “forecasts,” “should,” “could,” “would,” “will,” “confident,” “may,” “can,” “potential,” “possible,” “proposed,” “in process,” “construct,” “develop,” “opportunity,” “target,” “outlook,” “maintain,” “continue,” “progress,” “advance,” “goal,” “aim,” “commit,” or similar expressions, or when we discuss our guidance, priorities, strategy, goals, vision, mission, opportunities, projections, intentions or expectations.

Factors, among others, that could cause actual results and events to differ materially from those expressed or implied in any forward-looking statement include risks and uncertainties relating to:

▪California wildfires, including the risks that we may be found liable for damages regardless of fault and that we may not be able to recover all or a substantial portion of costs from insurance, the Wildfire Fund, in rates from customers or a combination thereof

▪decisions, investigations, regulations, issuances or revocations of permits and other authorizations, renewals of franchises, and other actions by (i) the CPUC, CRE, DOE, FERC, PUCT, and other regulatory and governmental bodies and (ii) the U.S., Mexico and states, counties, cities and other jurisdictions therein and in other countries in which we do business

▪the success of business development efforts, construction projects and acquisitions and divestitures, including risks in (i) being able to make a final investment decision, (ii) completing construction projects or other transactions on schedule and budget, (iii) realizing anticipated benefits from any of these efforts if completed, and (iv) obtaining the consent or approval of partners or other third parties, including governmental and regulatory bodies

▪civil and criminal litigation, regulatory inquiries, investigations, arbitrations, property disputes and other proceedings, including those related to the Leak

▪changes to laws and regulations, including certain of Mexico’s laws and rules that impact energy supplier permitting, energy contract rates, the electricity industry generally and the import, export, transport and storage of hydrocarbons

▪cybersecurity threats, including by state and state-sponsored actors, to the energy grid, storage and pipeline infrastructure, information and systems used to operate our businesses, and confidentiality of our proprietary information and personal information of our customers and employees, including ransomware attacks on our systems and the systems of third-parties with which we conduct business, all of which have become more pronounced due to recent geopolitical events and other uncertainties, such as the war in Ukraine

▪failure of foreign governments, state-owned entities and our counterparties to honor their contracts and commitments

▪actions by credit rating agencies to downgrade our credit ratings or to place those ratings on negative outlook and our ability to borrow on favorable terms and meet our debt service obligations

▪the impact of energy and climate policies, laws, rules and disclosures, as well as related goals and actions of companies in our industry, including actions to reduce or eliminate reliance on natural gas generally and any deterioration of or increased uncertainty in the political or regulatory environment for California natural gas distribution companies and the risk of nonrecovery for stranded assets

▪the pace of the development and adoption of new technologies in the energy sector, including those designed to support governmental and private party energy and climate goals, and our ability to timely and economically incorporate them into our businesses

▪weather, natural disasters, pandemics, accidents, equipment failures, explosions, acts of terrorism, information system outages or other events that disrupt our operations, damage our facilities and systems, cause the release of harmful materials, cause fires or subject us to liability for damages, fines and penalties, some of which may be disputed or not covered by insurers, may not be recoverable through regulatory mechanisms or may impact our ability to obtain satisfactory levels of affordable insurance

▪inflationary and interest rate pressures, volatility in foreign currency exchange rates and commodity prices, our ability to effectively hedge these risks, and their impact, as applicable, on SDG&E’s and SoCalGas’ cost of capital and the affordability of customer rates

▪the availability of electric power, natural gas and natural gas storage capacity, including disruptions caused by failures in the transmission grid or limitations on the withdrawal of natural gas from storage facilities

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▪the impact of the COVID-19 pandemic on capital projects, regulatory approvals and the execution of our operations

▪the impact at SDG&E on competitive customer rates and reliability due to growth in distributed and local power generation, including from departing retail load resulting from customers transferring to CCA and Direct Access, and the risk of nonrecovery for stranded assets and contractual obligations

▪Oncor’s ability to eliminate or reduce its quarterly dividends due to regulatory and governance requirements and commitments, including by actions of Oncor’s independent directors or a minority member director

▪changes in tax and trade policies, laws and regulations, including tariffs, revisions to international trade agreements and sanctions, such as those that have been imposed and that may be imposed in the future in connection with the war in Ukraine, which may increase our costs, reduce our competitiveness, impact our ability to do business with certain counterparties, or impair our ability to resolve trade disputes

▪other uncertainties, some of which are difficult to predict and beyond our control

We caution you not to rely unduly on any forward-looking statements. You should review and consider carefully the risks, uncertainties and other factors that affect our businesses as described herein, in our Annual Report and in other reports we file with the SEC.

8

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
	(unaudited)
REVENUES
Utilities:
Natural gas	$	1,704	$	1,278	$	4,024	$	3,055
Electric	1,189		1,156		2,306		2,224
Energy-related businesses	654		307		1,037		721
Total revenues	3,547		2,741		7,367		6,000
EXPENSES AND OTHER INCOME
Utilities:
Cost of natural gas	(528)		(261)		(1,330)		(610)
Cost of electric fuel and purchased power	(251)		(284)		(456)		(516)
Energy-related businesses cost of sales	(289)		(119)		(424)		(228)
Operation and maintenance	(1,162)		(1,024)		(2,248)		(2,025)
Aliso Canyon litigation and regulatory matters	(45)		—		(137)		—
Depreciation and amortization	(501)		(463)		(994)		(905)
Franchise fees and other taxes	(150)		(138)		(312)		(291)
Other (expense) income, net	(1)		72		37		107
Interest income	15		15		40		34
Interest expense	(271)		(258)		(514)		(517)
Income before income taxes and equity earnings	364		281		1,029		1,049
Income tax expense	(80)		(139)		(414)		(297)
Equity earnings	375		313		701		631
Net income	659		455		1,316		1,383
Earnings attributable to noncontrolling interests	(88)		(10)		(122)		(43)
Preferred dividends	(11)		(20)		(22)		(41)
Preferred dividends of subsidiary	(1)		(1)		(1)		(1)
Earnings attributable to common shares	$	559	$	424	$	1,171	$	1,298
Basic EPS:
Earnings	$	1.78	$	1.38	$	3.71	$	4.27
Weighted-average common shares outstanding	314,845		307,800		315,595		304,372
Diluted EPS:
Earnings	$	1.77	$	1.37	$	3.70	$	4.24
Weighted-average common shares outstanding	315,867		308,607		316,647		306,284

See Notes to Condensed Consolidated Financial Statements.

9

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Sempra Energy shareholders’ equity
	Pretax amount		Income tax (expense) benefit		Net-of-tax amount		Noncontrolling interests (after tax)		Total
	(unaudited)
	Three months ended June 30, 2022 and 2021
2022:
Net income	$	651	$	(80)	$	571	$	88	$	659
Other comprehensive income (loss):
Foreign currency translation adjustments	2		—		2		—		2
Financial instruments	65		(17)		48		15		63
Pension and other postretirement benefits	4		(1)		3		—		3
Total other comprehensive income	71		(18)		53		15		68
Comprehensive income	722		(98)		624		103		727
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	721	$	(98)	$	623	$	103	$	726
2021:
Net income	$	584	$	(139)	$	445	$	10	$	455
Other comprehensive income (loss):
Foreign currency translation adjustments	5		—		5		1		6
Financial instruments	(14)		2		(12)		(6)		(18)
Pension and other postretirement benefits	1		(1)		—		—		—
Total other comprehensive loss	(8)		1		(7)		(5)		(12)
Comprehensive income	576		(138)		438		5		443
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	575	$	(138)	$	437	$	5	$	442
	Six months ended June 30, 2022 and 2021
2022:
Net income	$	1,608	$	(414)	$	1,194	$	122	$	1,316
Other comprehensive income (loss):
Foreign currency translation adjustments	5		—		5		1		6
Financial instruments	167		(41)		126		35		161
Pension and other postretirement benefits	13		(2)		11		—		11
Total other comprehensive income	185		(43)		142		36		178
Comprehensive income	1,793		(457)		1,336		158		1,494
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	1,792	$	(457)	$	1,335	$	158	$	1,493
2021:
Net income	$	1,637	$	(297)	$	1,340	$	43	$	1,383
Other comprehensive income (loss):
Financial instruments	107		(27)		80		9		89
Pension and other postretirement benefits	18		(4)		14		—		14
Total other comprehensive income	125		(31)		94		9		103
Comprehensive income	1,762		(328)		1,434		52		1,486
Preferred dividends of subsidiary	(1)		—		(1)		—		(1)
Comprehensive income, after preferred dividends of subsidiary	$	1,761	$	(328)	$	1,433	$	52	$	1,485

See Notes to Condensed Consolidated Financial Statements.

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SEMPRA ENERGY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	1,931	$	559
Restricted cash	103		19
Accounts receivable – trade, net	1,839		2,071
Accounts receivable – other, net	323		398
Due from unconsolidated affiliates	646		23
Income taxes receivable	73		79
Inventories	377		389
Prepaid expenses	173		260
Regulatory assets	145		271
Greenhouse gas allowances	98		97
Other current assets	194		209
Total current assets	5,902		4,375
Other assets:
Restricted cash	59		3
Due from unconsolidated affiliates	—		637
Regulatory assets	2,465		2,011
Insurance receivable for Aliso Canyon costs	344		360
Greenhouse gas allowances	643		422
Nuclear decommissioning trusts	863		1,012
Dedicated assets in support of certain benefit plans	498		567
Deferred income taxes	138		151
Right-of-use assets – operating leases	580		594
Investment in Oncor Holdings	13,301		12,947
Other investments	1,792		1,525
Goodwill	1,602		1,602
Other intangible assets	357		370
Wildfire fund	317		331
Other long-term assets	1,319		1,244
Total other assets	24,278		23,776
Property, plant and equipment:
Property, plant and equipment	60,855		58,940
Less accumulated depreciation and amortization	(15,453)		(15,046)
Property, plant and equipment, net	45,402		43,894
Total assets	$	75,582	$	72,045

(1)    Derived from audited financial statements.

See Notes to Condensed Consolidated Financial Statements.

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SEMPRA ENERGY
CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	955	$	3,471
Accounts payable – trade	1,604		1,671
Accounts payable – other	215		178
Dividends and interest payable	609		563
Accrued compensation and benefits	334		479
Regulatory liabilities	307		359
Current portion of long-term debt and finance leases	303		106
Reserve for Aliso Canyon costs	2,003		1,980
Greenhouse gas obligations	98		97
Other current liabilities	1,122		1,131
Total current liabilities	7,550		10,035
Long-term debt and finance leases	24,661		21,068
Deferred credits and other liabilities:
Due to unconsolidated affiliates	282		287
Regulatory liabilities	3,295		3,402
Greenhouse gas obligations	392		225
Pension and other postretirement benefit plan obligations, net of plan assets	678		687
Deferred income taxes	4,212		3,477
Asset retirement obligations	3,467		3,375
Deferred credits and other	1,992		2,070
Total deferred credits and other liabilities	14,318		13,523
Commitments and contingencies (Note 11)
Equity:
Preferred stock (50 million shares authorized):
Preferred stock, series C (0.9 million shares outstanding)	889		889
Common stock (750 million shares authorized; 314 million and 317 million shares outstanding at June 30, 2022 and December 31, 2021, respectively; no par value)	12,121		11,862
Retained earnings	13,998		13,548
Accumulated other comprehensive income (loss)	(167)		(318)
Total Sempra Energy shareholders’ equity	26,841		25,981
Preferred stock of subsidiary	20		20
Other noncontrolling interests	2,192		1,418
Total equity	29,053		27,419
Total liabilities and equity	$	75,582	$	72,045

(1)    Derived from audited financial statements.

See Notes to Condensed Consolidated Financial Statements.

12

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Six months ended June 30,
	2022		2021
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,316	$	1,383
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	994		905
Deferred income taxes and investment tax credits	379		193
Equity earnings	(701)		(631)
Foreign currency transaction losses (gains), net	22		(7)
Share-based compensation expense	32		34
Fixed-price contracts and other derivatives	122		199
Other	101		54
Net change in working capital components	(3)		(63)
Insurance receivable for Aliso Canyon costs	16		31
Distributions from investments	403		532
Changes in other noncurrent assets and liabilities, net	(317)		(375)
Net cash provided by operating activities	2,364		2,255
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(2,361)		(2,424)
Expenditures for investments and acquisitions	(181)		(165)
Purchases of nuclear decommissioning trust assets	(397)		(542)
Proceeds from sales of nuclear decommissioning trust assets	397		542
Advances to unconsolidated affiliates	—		(8)
Distributions from investments	—		4
Other	7		5
Net cash used in investing activities	(2,535)		(2,588)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(711)		(634)
Preferred dividends paid	(22)		(68)
Issuances of common stock	3		5
Repurchases of common stock	(476)		(38)
Issuances of debt (maturities greater than 90 days)	4,818		285
Payments on debt (maturities greater than 90 days) and finance leases	(1,543)		(1,432)
(Decrease) increase in short-term debt, net	(2,011)		1,584
Advances from unconsolidated affiliates	18		20
Proceeds from sale of noncontrolling interests, net	1,732		7
Purchases of noncontrolling interests	—		(10)
Distributions to noncontrolling interests	(106)		—
Contributions from noncontrolling interests	13		—
Other	(30)		(1)
Net cash provided by (used in) financing activities	1,685		(282)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(2)		1
Increase (decrease) in cash, cash equivalents and restricted cash	1,512		(614)
Cash, cash equivalents and restricted cash, January 1	581		985
Cash, cash equivalents and restricted cash, June 30	$	2,093	$	371

See Notes to Condensed Consolidated Financial Statements.

13

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(Dollars in millions)
	Six months ended June 30,
	2022		2021
	(unaudited)
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	466	$	488
Income tax payments, net of refunds	233		73
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Increase in Cameron LNG JV investment for guarantee	—		22
Repayment of advances from unconsolidated affiliate in lieu of distribution	32		—
Accrued capital expenditures	476		526
Increase in finance lease obligations for investment in PP&E	22		24
Increase in ARO for investment in PP&E	55		8
Issuance of common stock in exchange for NCI and related AOCI	—		1,373
Common dividends declared but not paid	359		347
Conversion of mandatory convertible preferred stock	—		1,693
Preferred dividends declared but not paid	11		20

See Notes to Condensed Consolidated Financial Statements.

14

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Dollars in millions)
	Preferred stock		Common stock		Retained earnings		Accumulated other comprehensive income (loss)		Sempra Energy shareholders' equity		Non- controlling interests		Total equity
	(unaudited)
	Three months ended June 30, 2022
Balance at March 31, 2022	$	889	$	11,656	$	13,798	$	(229)	$	26,114	$	1,446	$	27,560
Net income					571				571		88		659
Other comprehensive income							53		53		15		68
Share-based compensation expense			15						15				15
Dividends declared:
Series C preferred stock ($12.19/share)					(11)				(11)				(11)
Common stock ($1.14/share)					(359)				(359)				(359)
Preferred dividends of subsidiary					(1)				(1)				(1)
Repurchases of common stock			(250)						(250)				(250)
Noncontrolling interest activities:
Contributions											7		7
Distributions											(53)		(53)
Sale			700				9		709		709		1,418
Balance at June 30, 2022	$	889	$	12,121	$	13,998	$	(167)	$	26,841	$	2,212	$	29,053
	Three months ended June 30, 2021
Balance at March 31, 2021	$	1,454	$	8,730	$	14,214	$	(399)	$	23,999	$	1,609	$	25,608
Net income					445				445		10		455
Other comprehensive loss							(7)		(7)		(5)		(12)
Share-based compensation expense			17						17				17
Dividends declared:
Series B preferred stock ($1.69/share)					(9)				(9)				(9)
Series C preferred stock ($12.19/share)					(11)				(11)				(11)
Common stock ($1.10/share)					(347)				(347)				(347)
Preferred dividends of subsidiary					(1)				(1)				(1)
Issuances of common stock			5						5				5
Repurchases of common stock			(1)						(1)				(1)
Noncontrolling interest activities:
Purchases			1,399				(38)		1,361		(1,373)		(12)
Balance at June 30, 2021	$	1,454	$	10,150	$	14,291	$	(444)	$	25,451	$	241	$	25,692

See Notes to Condensed Consolidated Financial Statements.

15

SEMPRA ENERGY
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Dollars in millions)
	Preferred stock		Common stock		Retained earnings		Accumulated other comprehensive income (loss)		Sempra Energy shareholders' equity		Non- controlling interests		Total equity
	(unaudited)
	Six months ended June 30, 2022
Balance at December 31, 2021	$	889	$	11,862	$	13,548	$	(318)	$	25,981	$	1,438	$	27,419
Net income					1,194				1,194		122		1,316
Other comprehensive income							142		142		36		178
Share-based compensation expense			32						32				32
Dividends declared:
Series C preferred stock ($24.38/share)					(22)				(22)				(22)
Common stock ($2.29/share)					(721)				(721)				(721)
Preferred dividends of subsidiary					(1)				(1)				(1)
Issuances of common stock			3						3				3
Repurchases of common stock			(476)						(476)				(476)
Noncontrolling interest activities:
Contributions											13		13
Distributions											(106)		(106)
Sale			700				9		709		709		1,418
Balance at June 30, 2022	$	889	$	12,121	$	13,998	$	(167)	$	26,841	$	2,212	$	29,053
	Six months ended June 30, 2021
Balance at December 31, 2020	$	3,147	$	7,053	$	13,673	$	(500)	$	23,373	$	1,561	$	24,934
Net income					1,340				1,340		43		1,383
Other comprehensive income							94		94		9		103
Share-based compensation expense			34						34				34
Dividends declared:
Series B preferred stock ($3.38/share)					(19)				(19)				(19)
Series C preferred stock ($24.38/share)					(22)				(22)				(22)
Common stock ($2.20/share)					(680)				(680)				(680)
Preferred dividends of subsidiary					(1)				(1)				(1)
Conversion of series A preferred stock	(1,693)		1,693						—				—
Issuances of common stock			5						5				5
Repurchases of common stock			(38)						(38)				(38)
Noncontrolling interest activities:
Purchases			1,399				(38)		1,361		(1,373)		(12)
Sale			4						4		1		5
Balance at June 30, 2021	$	1,454	$	10,150	$	14,291	$	(444)	$	25,451	$	241	$	25,692

See Notes to Condensed Consolidated Financial Statements.

16

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions)
		Three months ended June 30,				Six months ended June 30,
		2022		2021		2022		2021
	(unaudited)
Operating revenues
Electric		$	1,192	$	1,158	$	2,312	$	2,227
Natural gas		207		160		532		428
Total operating revenues		1,399		1,318		2,844		2,655
Operating expenses
Cost of electric fuel and purchased power		269		304		490		545
Cost of natural gas		69		40		195		122
Operation and maintenance		420		373		817		763
Depreciation and amortization		244		220		483		433
Franchise fees and other taxes		88		83		180		171
Total operating expenses		1,090		1,020		2,165		2,034
Operating income		309		298		679		621
Other income, net		22		22		56		57
Interest income		1		—		1		1
Interest expense		(114)		(101)		(220)		(203)
Income before income taxes		218		219		516		476
Income tax expense		(42)		(33)		(106)		(78)
Net income/Earnings attributable to common shares		$	176	$	186	$	410	$	398

See Notes to Condensed Financial Statements.

17

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Pretax amount		Income tax expense		Net-of-tax amount
	(unaudited)
	Three months ended June 30, 2022 and 2021
2022:
Net income/Comprehensive income	$	218	$	(42)	$	176
2021:
Net income/Comprehensive income	$	219	$	(33)	$	186
	Six months ended June 30, 2022 and 2021
2022:
Net income/Comprehensive income	$	516	$	(106)	$	410
2021:
Net income/Comprehensive income	$	476	$	(78)	$	398

See Notes to Condensed Financial Statements.

18

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	533	$	25
Accounts receivable – trade, net	685		715
Accounts receivable – other, net	72		78
Income taxes receivable, net	11		9
Inventories	124		123
Prepaid expenses	115		174
Regulatory assets	134		231
Greenhouse gas allowances	13		13
Other current assets	65		63
Total current assets	1,752		1,431
Other assets:
Regulatory assets	947		786
Greenhouse gas allowances	127		111
Nuclear decommissioning trusts	863		1,012
Right-of-use assets – operating leases	198		185
Wildfire fund	317		331
Other long-term assets	130		154
Total other assets	2,582		2,579
Property, plant and equipment:
Property, plant and equipment	27,201		26,456
Less accumulated depreciation and amortization	(6,460)		(6,408)
Property, plant and equipment, net	20,741		20,048
Total assets	$	25,075	$	24,058

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

19

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Short-term debt	$	—	$	776
Accounts payable	635		588
Due to unconsolidated affiliates	68		97
Interest payable	61		50
Accrued compensation and benefits	87		148
Regulatory liabilities	13		14
Current portion of long-term debt and finance leases	35		49
Customer deposits	27		30
Greenhouse gas obligations	13		13
Asset retirement obligations	94		86
Other current liabilities	281		260
Total current liabilities	1,314		2,111
Long-term debt and finance leases	8,958		7,581
Deferred credits and other liabilities:
Regulatory liabilities	2,213		2,302
Greenhouse gas obligations	57		31
Pension obligation, net of plan assets	24		25
Deferred income taxes	2,368		2,275
Asset retirement obligations	791		804
Deferred credits and other	691		680
Total deferred credits and other liabilities	6,144		6,117
Commitments and contingencies (Note 11)
Shareholder's equity:
Preferred stock (45 million shares authorized; none issued)	—		—
Common stock (255 million shares authorized; 117 million shares outstanding; no par value)	1,660		1,660
Retained earnings	7,009		6,599
Accumulated other comprehensive income (loss)	(10)		(10)
Total shareholder’s equity	8,659		8,249
Total liabilities and shareholder's equity	$	25,075	$	24,058

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

20

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Six months ended June 30,
	2022		2021
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	410	$	398
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	483		433
Deferred income taxes and investment tax credits	41		41
Other	19		(13)
Net change in working capital components	165		(136)
Changes in noncurrent assets and liabilities, net	(105)		(113)
Net cash provided by operating activities	1,013		610
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,090)		(1,072)
Purchases of nuclear decommissioning trust assets	(397)		(542)
Proceeds from sales of nuclear decommissioning trust assets	397		542
Other	8		7
Net cash used in investing activities	(1,082)		(1,065)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	1,395		—
Payments on debt (maturities greater than 90 days) and finance leases	(408)		(231)
(Decrease) increase in short-term debt, net	(401)		437
Debt issuance costs	(9)		—
Net cash provided by financing activities	577		206
Increase (decrease) in cash and cash equivalents	508		(249)
Cash and cash equivalents, January 1	25		262
Cash and cash equivalents, June 30	$	533	$	13
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	206	$	201
Income tax payments, net of refunds	68		58
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	186	$	192
Increase in ARO for investment in PP&E	1		18
Increase in finance lease obligations for investment in PP&E	9		13

See Notes to Condensed Financial Statements.

21

SAN DIEGO GAS & ELECTRIC COMPANY
CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY
(Dollars in millions)
	Common stock		Retained earnings		Accumulated other comprehensive income (loss)		Total shareholder's equity
	(unaudited)
	Three months ended June 30, 2022
Balance at March 31, 2022	$	1,660	$	6,833	$	(10)	$	8,483
Net income			176				176
Balance at June 30, 2022	$	1,660	$	7,009	$	(10)	$	8,659
	Three months ended June 30, 2021
Balance at March 31, 2021	$	1,660	$	6,292	$	(10)	$	7,942
Net income			186				186
Balance at June 30, 2021	$	1,660	$	6,478	$	(10)	$	8,128
	Six months ended June 30, 2022
Balance at December 31, 2021	$	1,660	$	6,599	$	(10)	$	8,249
Net income			410				410
Balance at June 30, 2022	$	1,660	$	7,009	$	(10)	$	8,659
	Six months ended June 30, 2021
Balance at December 31, 2020	$	1,660	$	6,080	$	(10)	$	7,730
Net income			398				398
Balance at June 30, 2021	$	1,660	$	6,478	$	(10)	$	8,128

See Notes to Condensed Financial Statements.

22

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF OPERATIONS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
	(unaudited)
Operating revenues	$	1,501	$	1,124	$	3,494	$	2,632
Operating expenses
Cost of natural gas	459		223		1,136		496
Operation and maintenance	605		525		1,156		1,028
Aliso Canyon litigation and regulatory matters	45		—		137		—
Depreciation and amortization	188		180		375		353
Franchise fees and other taxes	57		51		119		109
Total operating expenses	1,354		979		2,923		1,986
Operating income	147		145		571		646
Other income (expense), net	4		(2)		38		37
Interest income	1		—		1		—
Interest expense	(45)		(40)		(85)		(79)
Income before income taxes	107		103		525		604
Income tax expense	(19)		(8)		(103)		(102)
Net income	88		95		422		502
Preferred dividends	(1)		(1)		(1)		(1)
Earnings attributable to common shares	$	87	$	94	$	421	$	501

See Notes to Condensed Financial Statements.

23

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Pretax amount		Income tax expense		Net-of-tax amount
	(unaudited)
	Three months ended June 30, 2022 and 2021
2022:
Net income	$	107	$	(19)	$	88
Other comprehensive income (loss):
Financial instruments	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	108	$	(19)	$	89
2021:
Net income	$	103	$	(8)	$	95
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	104	$	(8)	$	96
	Six months ended June 30, 2022 and 2021
2022:
Net income	$	525	$	(103)	$	422
Other comprehensive income (loss):
Financial instruments	1		—		1
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	2		—		2
Comprehensive income	$	527	$	(103)	$	424
2021:
Net income	$	604	$	(102)	$	502
Other comprehensive income (loss):
Pension and other postretirement benefits	1		—		1
Total other comprehensive income	1		—		1
Comprehensive income	$	605	$	(102)	$	503

See Notes to Condensed Financial Statements.

24

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	416	$	37
Accounts receivable – trade, net	722		1,084
Accounts receivable – other, net	48		58
Due from unconsolidated affiliates	31		49
Income taxes receivable, net	23		23
Inventories	169		172
Regulatory assets	11		40
Greenhouse gas allowances	76		75
Other current assets	32		61
Total current assets	1,528		1,599
Other assets:
Regulatory assets	1,441		1,148
Insurance receivable for Aliso Canyon costs	344		360
Greenhouse gas allowances	488		290
Right-of-use assets – operating leases	49		57
Other long-term assets	616		627
Total other assets	2,938		2,482
Property, plant and equipment:
Property, plant and equipment	23,975		23,104
Less accumulated depreciation and amortization	(7,087)		(6,861)
Property, plant and equipment, net	16,888		16,243
Total assets	$	21,354	$	20,324

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

25

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	June 30,		December 31,
	2022		2021(1)
	(unaudited)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Short-term debt	$	—	$	385
Accounts payable – trade	647		775
Accounts payable – other	152		142
Due to unconsolidated affiliates	36		36
Accrued compensation and benefits	159		202
Regulatory liabilities	294		345
Current portion of long-term debt and finance leases	13		11
Customer deposits	15		13
Reserve for Aliso Canyon costs	2,003		1,980
Greenhouse gas obligations	76		75
Asset retirement obligations	76		77
Other current liabilities	230		271
Total current liabilities	3,701		4,312
Long-term debt and finance leases	5,471		4,773
Deferred credits and other liabilities:
Regulatory liabilities	1,082		1,100
Greenhouse gas obligations	303		174
Pension obligation, net of plan assets	545		551
Deferred income taxes	1,212		1,039
Asset retirement obligations	2,609		2,505
Deferred credits and other	416		428
Total deferred credits and other liabilities	6,167		5,797
Commitments and contingencies (Note 11)
Shareholders’ equity:
Preferred stock (11 million shares authorized; 1 million shares outstanding)	22		22
Common stock (100 million shares authorized; 91 million shares outstanding; no par value)	1,816		1,666
Retained earnings	4,206		3,785
Accumulated other comprehensive income (loss)	(29)		(31)
Total shareholders’ equity	6,015		5,442
Total liabilities and shareholders’ equity	$	21,354	$	20,324

(1)    Derived from audited financial statements.

See Notes to Condensed Financial Statements.

26

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Six months ended June 30,
	2022		2021
	(unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	422	$	502
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	375		353
Deferred income taxes and investment tax credits	103		18
Other	36		42
Net change in working capital components	225		297
Insurance receivable for Aliso Canyon costs	16		31
Changes in other noncurrent assets and liabilities, net	(316)		(280)
Net cash provided by operating activities	861		963
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(931)		(936)
Net cash used in investing activities	(931)		(936)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)		(1)
Common dividends paid	—		(50)
Equity contribution from Sempra Energy	150		—
Issuances of debt (maturities greater than 90 days)	697		—
Payments on finance leases	(6)		(6)
(Decrease) increase in short-term debt, net	(385)		30
Debt issuance costs	(6)		—
Net cash provided by (used in) financing activities	449		(27)
Increase in cash and cash equivalents	379		—
Cash and cash equivalents, January 1	37		4
Cash and cash equivalents, June 30	$	416	$	4
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	$	75	$	76
Income tax payments, net of refunds	—		82
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$	199	$	156
Increase (decrease) in ARO for investment in PP&E	54		(10)
Increase in finance lease obligations for investment in PP&E	13		11
Common dividends declared but not paid	—		25

See Notes to Condensed Financial Statements.

27

SOUTHERN CALIFORNIA GAS COMPANY
CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Dollars in millions)
	Preferred stock		Common stock		Retained earnings		Accumulated other comprehensive income (loss)		Total shareholders’ equity
	(unaudited)
	Three months ended June 30, 2022
Balance at March 31, 2022	$	22	$	1,666	$	4,119	$	(30)	$	5,777
Net income					88				88
Other comprehensive income							1		1
Dividends declared:
Preferred stock ($0.37/share)					(1)				(1)
Equity contribution from Sempra Energy			150						150
Balance at June 30, 2022	$	22	$	1,816	$	4,206	$	(29)	$	6,015
	Three months ended June 30, 2021
Balance at March 31, 2021	$	22	$	866	$	4,644	$	(31)	$	5,501
Net income					95				95
Other comprehensive income							1		1
Dividends declared:
Preferred stock ($0.37/share)					(1)				(1)
Common stock ($0.27/share)					(25)				(25)
Balance at June 30, 2021	$	22	$	866	$	4,713	$	(30)	$	5,571
	Six months ended June 30, 2022
Balance at December 31, 2021	$	22	$	1,666	$	3,785	$	(31)	$	5,442
Net income					422				422
Other comprehensive income							2		2
Dividends declared:
Preferred stock ($0.75/share)					(1)				(1)
Equity contribution from Sempra Energy			150						150
Balance at June 30, 2022	$	22	$	1,816	$	4,206	$	(29)	$	6,015
	Six months ended June 30, 2021
Balance at December 31, 2020	$	22	$	866	$	4,287	$	(31)	$	5,144
Net income					502				502
Other comprehensive income							1		1
Dividends declared:
Preferred stock ($0.75/share)					(1)				(1)
Common stock ($0.82/share)					(75)				(75)
Balance at June 30, 2021	$	22	$	866	$	4,713	$	(30)	$	5,571

See Notes to Condensed Financial Statements.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1. GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, which resulted in a change to our reportable segments. Historical segment disclosures have been restated to conform with the current presentation of our four separate reportable segments, which we discuss in Note 12. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name.

SDG&E

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

SoCalGas

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

BASIS OF PRESENTATION

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

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2022 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, 2021 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2021 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.

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Our Sempra Infrastructure segment includes the operating companies of our subsidiary, IEnova, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

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

Restricted cash includes:

▪for Sempra Infrastructure, funds fully drawn against Gazprom’s letters of credit, including draws associated with its LNG storage and regasification agreement that we discuss in Note 11, and funds denominated in Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects

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

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

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2022		December 31, 2021
Cash and cash equivalents	$	1,931	$	559
Restricted cash, current	103		19
Restricted cash, noncurrent	59		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	2,093	$	581

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 6.

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

In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and applied the amounts directly to eligible customer accounts to reduce past due balances. In June 2022, AB 205 was approved establishing, among other things, the 2022 California Arrearage Payment Program. SDG&E and SoCalGas expect to apply for funding from this program on behalf of their residential customers with past due balances and, if approved, receive such funding in the first quarter of 2023.

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

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RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2022		2021
Sempra:
Allowances for credit losses at January 1	$	136	$	138
Provisions for expected credit losses	77		66
Write-offs	(36)		(12)
Allowances for credit losses at June 30	$	177	$	192
SDG&E:
Allowances for credit losses at January 1	$	66	$	69
Provisions for expected credit losses	37		13
Write-offs	(18)		(7)
Allowances for credit losses at June 30	$	85	$	75
SoCalGas:
Allowances for credit losses at January 1	$	69	$	68
Provisions for expected credit losses	37		52
Write-offs	(18)		(5)
Allowances for credit losses at June 30	$	88	$	115

Allowances for credit losses related to accounts receivable are included in the Condensed Consolidated Balance Sheets as follows:

ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2022		2021
Sempra:
Accounts receivable – trade, net	$	142	$	94
Accounts receivable – other, net	33		39
Other long-term assets	2		3
Total allowances for credit losses	$	177	$	136
SDG&E:
Accounts receivable – trade, net	$	62	$	42
Accounts receivable – other, net	22		22
Other long-term assets	1		2
Total allowances for credit losses	$	85	$	66
SoCalGas:
Accounts receivable – trade, net	$	76	$	51
Accounts receivable – other, net	11		17
Other long-term assets	1		1
Total allowances for credit losses	$	88	$	69

As we discuss below in “Transactions with Affiliates,” we have loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on amounts due from unconsolidated affiliates, if necessary, based on credit quality indicators such as external credit ratings, published default rate studies, the maturity date of the instrument and past delinquencies. However, we do not record allowances for expected credit losses related to accrued interest receivable on loans due from unconsolidated affiliates because we write off such amounts, if any, through a reversal of interest income in the period we determine such amounts are uncollectible. In the absence of external credit ratings, we may utilize an internally developed credit rating based on our analysis of a counterparty’s financial statements to determine our expected credit losses. At December 31, 2021, $1 million of expected credit losses are included in noncurrent Due From Unconsolidated Affiliates on Sempra’s Condensed Consolidated Balance Sheet.

As we discuss below in “Note Receivable,” we have an interest-bearing promissory note due from KKR. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on this note receivable, including compounded interest and unamortized transaction costs, based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At June 30, 2022 and December 31, 2021, $7 million and $8 million, respectively, of expected credit losses are included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheets.

As we discuss below in Note 6, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn

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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 June 30, 2022 and December 31, 2021, $6 million and $7 million, respectively, of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets.

INVENTORIES

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Natural gas	$	138	$	164	$	—	$	—	$	102	$	114
LNG	31		27		—		—		—		—
Materials and supplies	208		198		124		123		67		58
Total	$	377	$	389	$	124	$	123	$	169	$	172

NOTE RECEIVABLE

In October 2021, Sempra loaned $300 million to KKR 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. At June 30, 2022 and December 31, 2021, Other Long-Term Assets includes $308 million and $297 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, and at December 31, 2021, Other Current Assets includes $3 million of interest receivable on Sempra’s Condensed Consolidated Balance Sheets.

CAPITALIZED FINANCING COSTS

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

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

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra	$	60	$	55	$	117	$	114
SDG&E	26		28		54		58
SoCalGas	17		15		35		31

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.

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SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at June 30, 2022 and December 31, 2021. 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 $1,206 million and $1,217 million at June 30, 2022 and December 31, 2021, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Sempra Texas Utilities

Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $13,301 million at June 30, 2022 and $12,947 million at December 31, 2021.

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 $723 million at June 30, 2022 and $514 million at December 31, 2021. 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 6.

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CFIN

As we discuss in Note 6, 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 9). 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 development activities related to the construction of the liquefaction facility, which we consider to be the most significant activities of ECA LNG Phase 1 during the construction phase of its natural gas liquefaction export project. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $767 million and $632 million of assets at June 30, 2022 and December 31, 2021, respectively, consisting primarily of PP&E, net, and Accounts Receivable – Other attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $532 million and $455 million of liabilities at June 30, 2022 and December 31, 2021, respectively, consisting primarily of long-term debt, short-term debt and accounts payable attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 7, Sempra and TotalEnergies SE have provided guarantees for the loan facility supporting construction of the liquefaction facility based on their respective proportionate ownership interest in ECA LNG Phase 1.

PENSION AND OTHER POSTRETIREMENT BENEFITS

Net Periodic Benefit Cost

The following three 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 (Expense) Income, Net, table below.

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NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	42	$	36	$	6	$	5
Interest cost	29		28		7		7
Expected return on assets	(45)		(43)		(16)		(15)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	5		11		(3)		(2)
Net periodic benefit cost (credit)	33		34		(6)		(5)
Regulatory adjustments	24		22		6		5
Total expense recognized	$	57	$	56	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	83	$	73	$	13	$	11
Interest cost	59		56		14		14
Expected return on assets	(91)		(86)		(32)		(30)
Amortization of:
Prior service cost (credit)	5		5		(1)		(1)
Actuarial loss (gain)	11		22		(7)		(4)
Settlement charges	—		7		—		—
Net periodic benefit cost (credit)	67		77		(13)		(10)
Regulatory adjustments	(3)		(7)		13		10
Total expense recognized	$	64	$	70	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	10	$	9	$	1	$	1
Interest cost	6		6		2		2
Expected return on assets	(11)		(13)		(3)		(3)
Amortization of:
Actuarial loss (gain)	1		1		—		(1)
Net periodic benefit cost (credit)	6		3		—		(1)
Regulatory adjustments	7		11		—		1
Total expense recognized	$	13	$	14	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	20	$	17	$	3	$	2
Interest cost	13		12		3		3
Expected return on assets	(22)		(25)		(5)		(5)
Amortization of:
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	12		5		—		(1)
Regulatory adjustments	2		9		—		1
Total expense recognized	$	14	$	14	$	—	$	—

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NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	28	$	25	$	5	$	4
Interest cost	21		20		6		6
Expected return on assets	(33)		(30)		(14)		(12)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	4		10		(3)		(2)
Net periodic benefit cost (credit)	22		27		(6)		(4)
Regulatory adjustments	17		11		6		4
Total expense recognized	$	39	$	38	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	56	$	50	$	10	$	8
Interest cost	41		40		11		11
Expected return on assets	(64)		(58)		(27)		(24)
Amortization of:
Prior service cost (credit)	4		4		(1)		(1)
Actuarial loss (gain)	8		19		(6)		(3)
Net periodic benefit cost (credit)	45		55		(13)		(9)
Regulatory adjustments	(5)		(16)		13		9
Total expense recognized	$	40	$	39	$	—	$	—

RABBI TRUST

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 $498 million and $567 million at June 30, 2022 and December 31, 2021, respectively.

SEMPRA EARNINGS PER COMMON SHARE

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

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EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Numerator:
Earnings attributable to common shares	$	559	$	424	$	1,171	$	1,298
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	314,845		307,800		315,595		304,372
Dilutive effect of stock options and RSUs(2)	1,022		807		1,052		846
Dilutive effect of mandatory convertible preferred stock	—		—		—		1,066
Weighted-average common shares outstanding for diluted EPS	315,867		308,607		316,647		306,284
EPS:
Basic	$	1.78	$	1.38	$	3.71	$	4.27
Diluted	$	1.77	$	1.37	$	3.70	$	4.24

(1)    Includes 399 and 447 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2022 and 2021, respectively, and 403 and 454 of such RSUs for the six months ended June 30, 2022 and 2021, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and six months ended June 30, 2022 excludes 8,899 and 173,064 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and six months ended June 30, 2021 excludes 145,247 and 287,061 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

In 2021, the potentially dilutive impact from mandatory convertible preferred stock was calculated under the if-converted method until the mandatory conversion date. After the mandatory conversion date, the converted shares are included in weighted-average common shares outstanding for basic EPS. We converted all of our series A preferred stock into common stock on January 15, 2021 and all of our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for both the three months and six months ended June 30, 2021 excludes 4,256,725 potentially dilutive shares.

In January 2022, pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Committee of Sempra’s board of directors granted 219,898 nonqualified stock options, 338,080 performance-based RSUs and 150,286 service-based RSUs.

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

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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 other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended June 30, 2022 and 2021
Sempra:
Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
OCI before reclassifications	1		37		1		39
Amounts reclassified from AOCI(2)	10		11		2		23
Net OCI(2)	11		48		3		62
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance at March 31, 2021	$	(69)	$	(239)	$	(91)	$	(399)
OCI before reclassifications(3)	(19)		(36)		(2)		(57)
Amounts reclassified from AOCI	—		10		2		12
Net OCI(3)	(19)		(26)		—		(45)
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at March 31, 2022 and June 30, 2022					$	(10)	$	(10)
Balance at March 31, 2021 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance at March 31, 2022			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)
Balance at March 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).

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CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) (CONTINUED)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
	Six months ended June 30, 2022 and 2021
Sempra:
Balance as of December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		111		7		122
Amounts reclassified from AOCI(2)	10		15		4		29
Net OCI(2)	14		126		11		151
Balance as of June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications(3)	(24)		37		5		18
Amounts reclassified from AOCI	—		29		9		38
Net OCI(3)	(24)		66		14		56
Balance as of June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at December 31, 2021 and June 30, 2022					$	(10)	$	(10)
Balance at December 31, 2020 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance as of December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance as of June 30, 2022			$	(12)	$	(17)	$	(29)
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, which we discuss below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction did not impact the Condensed Consolidated Statement of Comprehensive Income (Loss).

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RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	13		19		Equity Earnings(1)
Foreign exchange instruments	(1)		—		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	—		(7)		Other (Expense) Income, Net
Total, before income tax	12		11
	(4)		(1)		Income Tax Expense
Total, net of income tax	8		10
	3		—		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	11	$	10
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	2	$	1	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total, before income tax	3		2
	(1)		—		Income Tax Expense
Total, net of income tax	$	2	$	2
Total reclassifications for the period, net of income  tax and NCI	$	14	$	12
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	—	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of income  tax	$	1	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

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RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	(1)	$	1	Interest Expense
Interest rate instruments	27		38		Equity Earnings(1)
Foreign exchange instruments	(2)		1		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Foreign exchange instruments	(1)		1		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	(6)		(1)		Other (Expense) Income, Net
Total, before income tax	17		40
	(5)		(9)		Income Tax Expense
Total, net of income tax	12		31
	3		(2)		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	15	$	29
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	4	$	3	Other (Expense) Income, Net
Amortization of prior service cost	2		2		Other (Expense) Income, Net
Settlement charges	—		7		Other (Expense) Income, Net
Total, before income tax	6		12
	(2)		(3)		Income Tax Expense
Total, net of income tax	$	4	$	9
Total reclassifications for the period, net of income  tax and NCI	$	20	$	38
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other Income (Expense), Net
Amortization of prior service cost	—		1		Other Income (Expense), Net
Total, before income tax	1		1
	—		—		Income Tax Expense
Total, net of income tax	$	1	$	1
Total reclassifications for the period, net of income  tax	$	2	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

For the three months and six months ended June 30, 2022 and 2021, reclassifications out of AOCI to net income were negligible for SDG&E.

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SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Series A Preferred Stock

On January 15, 2021, we converted all 17,250,000 shares of series A preferred stock into 13,781,025 shares of our common stock based on a conversion rate of 0.7989 shares of our common stock for each issued and outstanding share of series A preferred stock. As a consequence, no shares of series A preferred stock were outstanding after January 15, 2021 and the 17,250,000 shares that were formerly series A preferred stock returned to the status of authorized and unissued shares of preferred stock.

Sempra Common Stock Repurchases

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

On April 6, 2022, we entered into an ASR program under which we prepaid $250 million to repurchase shares of our common stock in a share forward transaction. A total of 1,471,957 shares were purchased under this program at an average price of $169.84 per share. The total number of shares purchased was determined by dividing the $250 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of April 7, 2022 through April 25, 2022, minus a fixed discount. The ASR program was completed on April 25, 2022.

Other Noncontrolling Interests

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

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Sempra Infrastructure:
SI Partners	30.0	%	20.0	%	$	2,146	$	1,384
SI Partners subsidiaries(1)	0.1 - 16.6		0.1 - 16.6		46		34
Total Sempra					$	2,192	$	1,418

(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 in SI Partners to ADIA. On June 1, 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 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 $709 million, net of $12 million in transaction costs and $301 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.

At the closing of the sale of NCI in SI Partners to ADIA, SI Partners indirectly owned 99.9% of the outstanding shares of IEnova. To the extent we acquire additional shares of IEnova after the closing, such additional shares will be acquired by SI Partners, and KKR and ADIA will provide 20% and 10%, respectively, of the funding.

At the closing, KKR and ADIA (the Minority Partners) and Sempra entered into a second amended and restated agreement of limited partnership of SI Partners (the Amended LP Agreement), which governs their respective rights and obligations in respect of their ownership of SI Partners. Under the Amended LP Agreement, matters are decided generally by majority vote and the managers designated by Sempra, KKR and ADIA each, as a group, have voting power equivalent to the ownership percentage of their respective designating limited partner. Sempra maintains control of SI Partners. However, SI Partners and its controlled subsidiaries are prohibited from taking certain limited actions without the prior written approval of the Minority Partners (subject

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to each Minority Partner maintaining certain ownership thresholds in SI Partners). The minority protections held by ADIA constitute a subset of the minority protections granted to KKR.

The terms of the Amended LP Agreement applicable to ADIA in relation to capital contributions and distributions are generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including limiting ADIA’s priority distribution rights to the failure of certain proposed projects to receive a positive final investment decision by a certain date or to achieve specified thresholds of projected internal rates of return or leverage. The transfer rights and restrictions and registration rights in the Amended LP Agreement applicable to ADIA are also generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including a general restriction on ADIA transferring its interests in SI Partners to third parties (other than pursuant to certain specified permitted transfers) for a specified period following its entry into the Amended LP Agreement.

SI Partners Subsidiaries. In May 2021, we acquired 381,015,194 publicly owned shares of IEnova in exchange for 12,306,777 newly issued shares of our common stock upon completion of our exchange offer launched in the U.S. and Mexico, which increased our ownership interest in IEnova from 70.2% to 96.4%. We acquired the IEnova shares at an exchange ratio of 0.0323 shares of our common stock for each one IEnova share. In connection with the exchange offer, we recorded a $1.4 billion decrease in equity held by NCI and an increase in Sempra’s shareholders’ equity of $1.4 billion, net of $12 million in transactions costs.

Following the exchange offer we completed in May 2021 and a subsequent cash tender offer we completed in September 2021, IEnova’s shares were delisted from the Mexican Stock Exchange effective October 15, 2021. In connection with the delisting, we are maintaining a trust for the purpose of purchasing the 1,212,981 IEnova shares that remained publicly owned as of the completion of the cash tender offer for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust was to be in place through the earlier of April 14, 2022 or the date on which we acquired all the remaining publicly owned IEnova shares. On April 13, 2022, the term of the trust was amended so that it will remain in place until we terminate it, subject to any maximum term under applicable Mexican law. As of August 1, 2022, an aggregate of 851,211 of the remaining publicly owned IEnova shares had been acquired by such trust.

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TRANSACTIONS WITH AFFILIATES

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Sempra Infrastructure – IMG – Note due March 15, 2023(1)	$	626	$	2
Various affiliates	20		21
Total due from unconsolidated affiliates – current	$	646	$	23
Sempra Infrastructure – IMG – Note due March 15, 2022, net of allowance for credit losses of $1 at December 31, 2021(1)	$	—	$	637
Total due from unconsolidated affiliates – noncurrent	$	—	$	637
Sempra Infrastructure(2):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	(39)	$	(69)
5.5% Note due January 14, 2025	(22)		(21)
5.5% Note due July 16, 2025	(21)		(20)
5.5% Note due January 14, 2026	(18)		—
TAG – 5.74% Note due December 17, 2029	(182)		(177)
Total due to unconsolidated affiliates – noncurrent	$	(282)	$	(287)
SDG&E:
Sempra	$	(26)	$	(40)
SoCalGas	(30)		(48)
Various affiliates	(12)		(9)
Total due to unconsolidated affiliates – current	$	(68)	$	(97)
Income taxes due from Sempra(3)	$	21	$	19
SoCalGas:
SDG&E	$	30	$	48
Various affiliates	1		1
Total due from unconsolidated affiliates – current	$	31	$	49
Sempra	$	(36)	$	(36)
Total due to unconsolidated affiliates – current	$	(36)	$	(36)
Income taxes due from Sempra(3)	$	6	$	6

(1)    At December 31, 2021, represents a Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $691 U.S. dollar-equivalent at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps. In March 2022, Sempra Infrastructure amended and restated the revolving line of credit to a U.S. dollar-denominated note in the amount of $625 at a variable interest rate based on the adjusted 1-month Secured Overnight Financing Rate plus 180 bps (3.41% at June 30, 2022) and extended the maturity date to March 15, 2023. At June 30, 2022 and December 31, 2021, $1 and $2 of accrued interest receivable, respectively, is included in Due from Unconsolidated Affiliates – Current. In July 2022, this note receivable was paid in full.

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

(3)    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.

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The following table summarizes income statement information from unconsolidated affiliates.

INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Revenues	$	15	$	7	$	22	$	15
Cost of sales	—		—		—		11
Interest income	4		12		14		27
Interest expense	4		3		8		7
SDG&E:
Revenues	$	4	$	2	$	8	$	4
Cost of sales	26		27		50		55
SoCalGas:
Revenues	$	23	$	23	$	49	$	48
Cost of sales(1)	(4)		—		(4)		3

(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 6 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

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OTHER (EXPENSE) INCOME, NET

Other (expense) income, net, consists of the following:

OTHER (EXPENSE) INCOME, NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Allowance for equity funds used during construction	$	34	$	34	$	69	$	72
Investment (losses) gains, net(1)	(34)		19		(47)		28
(Losses) gains on interest rate and foreign exchange instruments, net	(1)		7		5		(23)
Foreign currency transaction (losses) gains, net(2)	(3)		26		(22)		7
Non-service components of net periodic benefit (cost) credit	(9)		(15)		32		14
Interest on regulatory balancing accounts, net	4		2		5		3
Sundry, net	8		(1)		(5)		6
Total	$	(1)	$	72	$	37	$	107
SDG&E:
Allowance for equity funds used during construction	$	21	$	22	$	42	$	45
Non-service components of net periodic benefit (cost) credit	(2)		(4)		9		5
Interest on regulatory balancing accounts, net	3		2		4		3
Sundry, net	—		2		1		4
Total	$	22	$	22	$	56	$	57
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	26	$	23
Non-service components of net periodic benefit (cost) credit	(6)		(9)		26		19
Interest on regulatory balancing accounts, net	1		—		1		—
Sundry, net	(4)		(4)		(15)		(5)
Total	$	4	$	(2)	$	38	$	37

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

(2)    Includes losses of $11 in the six months ended June 30, 2022 and gains of $28 and $5 in the three months and six months ended June 30, 2021, respectively, 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 Statements of Operations.

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INCOME TAXES

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2022			2021			2022			2021
Sempra:
Income tax expense	$	80		$	139		$	414		$	297
Income before income taxes and equity earnings	$	364		$	281		$	1,029		$	1,049
Equity earnings, before income tax(1)	159			185			302			320
Pretax income	$	523		$	466		$	1,331		$	1,369
Effective income tax rate	15		%	30		%	31		%	22		%
SDG&E:
Income tax expense	$	42		$	33		$	106		$	78
Income before income taxes	$	218		$	219		$	516		$	476
Effective income tax rate	19		%	15		%	21		%	16		%
SoCalGas:
Income tax expense	$	19		$	8		$	103		$	102
Income before income taxes	$	107		$	103		$	525		$	604
Effective income tax rate	18		%	8		%	20		%	17		%

(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 or benefit, 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

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

In the six months ended June 30, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested.

NOTE 2. NEW ACCOUNTING STANDARDS

We describe below recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures.

ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and

47

contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We adopted the standard on January 1, 2022 using a modified retrospective approach and the adoption did not materially impact our financial statements or per-share amounts.

NOTE 3. 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.

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

DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2022
By major service line:
Utilities	$	1,250	$	1,347	$	20	$	(27)	$	2,590
Energy-related businesses	—		—		457		(14)		443
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
By market:
Gas	$	159	$	1,347	$	340	$	(19)	$	1,827
Electric	1,091		—		137		(22)		1,206
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Utilities regulatory revenues	149		154		—		—		303
Other revenues	—		—		212		(1)		211
Total revenues	$	1,399	$	1,501	$	689	$	(42)	$	3,547
	Six months ended June 30, 2022
By major service line:
Utilities	$	2,751	$	3,259	$	48	$	(56)	$	6,002
Energy-related businesses	—		—		749		(29)		720
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
By market:
Gas	$	489	$	3,259	$	569	$	(45)	$	4,272
Electric	2,262		—		228		(40)		2,450
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Utilities regulatory revenues	93		235		—		—		328
Other revenues	—		—		316		1		317
Total revenues	$	2,844	$	3,494	$	1,113	$	(84)	$	7,367

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DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2021
By major service line:
Utilities	$	1,170	$	1,062	$	17	$	(25)	$	2,224
Energy-related businesses	—		—		260		(14)		246
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
By market:
Gas	$	162	$	1,062	$	185	$	(24)	$	1,385
Electric	1,008		—		92		(15)		1,085
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Utilities regulatory revenues	148		62		—		—		210
Other revenues	—		—		64		(3)		61
Total revenues	$	1,318	$	1,124	$	341	$	(42)	$	2,741
	Six months ended June 30, 2021
By major service line:
Utilities	$	2,386	$	2,719	$	44	$	(52)	$	5,097
Energy-related businesses	—		—		529		(15)		514
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
By market:
Gas	$	435	$	2,719	$	397	$	(48)	$	3,503
Electric	1,951		—		176		(19)		2,108
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Utilities regulatory revenues	269		(87)		—		—		182
Other revenues	—		—		217		(10)		207
Total revenues	$	2,655	$	2,632	$	790	$	(77)	$	6,000

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations

For contracts greater than one year, at June 30, 2022, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2022.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2022 (excluding first six months of 2022)	$	200	$	2
2023	384		4
2024	385		4
2025	384		4
2026	382		4
Thereafter	4,525		63
Total revenues to be recognized	$	6,260	$	81

(1)    Excludes intercompany transactions.

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Contract Liabilities from Revenues from Contracts with Customers

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2022 or 2021. As we discuss in Note 11, Sempra Infrastructure drew against and fully exhausted Gazprom’s letters of credit in April 2022 due to Gazprom’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance. Gazprom has not paid its invoices since March 2022, so funds drawn from the letters of credit have been used to fully offset such nonpayment, which have been reflected as revenue from performance obligations satisfied during the reporting period. We expect that these funds will provide payment security from Gazprom through the end of 2024.

CONTRACT LIABILITIES
(Dollars in millions)
	2022		2021
Sempra:
Contract liabilities at January 1	$	(278)	$	(207)
Revenue from performance obligations satisfied during reporting period	86		49
Payments received in advance	(105)		(1)
Contract liabilities at June 30(1)	$	(297)	$	(159)
SDG&E:
Contract liabilities at January 1	$	(83)	$	(87)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(1)	$	(81)	$	(85)

(1)     Balances at June 30, 2022 include $81 and $4 in Other Current Liabilities and $216 and $77 in Deferred Credits and Other on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets, respectively.

Receivables from Revenues from Contracts with Customers

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Accounts receivable – trade, net	$	1,620	$	1,886
Accounts receivable – other, net	13		19
Due from unconsolidated affiliates – current(1)	5		2
Other long-term assets(2)	32		70
Total	$	1,670	$	1,977
SDG&E:
Accounts receivable – trade, net	$	685	$	715
Accounts receivable – other, net	11		9
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets(2)	17		25
Total	$	716	$	751
SoCalGas:
Accounts receivable – trade, net	$	722	$	1,084
Accounts receivable – other, net	2		10
Other long-term assets(2)	15		45
Total	$	739	$	1,139

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

(2)     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.

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NOTE 4. REGULATORY MATTERS

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2022		December 31, 2021
SDG&E:
Fixed-price contracts and other derivatives	$	(24)	$	(50)
Deferred income taxes recoverable in rates	176		125
Pension and other postretirement benefit plan obligations	(8)		(7)
Removal obligations	(2,185)		(2,251)
Environmental costs	61		62
Sunrise Powerlink fire mitigation	121		122
Regulatory balancing accounts(1)(2)
Commodity – electric	246		77
Gas transportation	33		49
Safety and reliability	80		67
Public purpose programs	(117)		(107)
Wildfire mitigation plan	255		178
Liability insurance premium	102		110
Other balancing accounts	(17)		207
Other regulatory assets, net(2)	132		119
Total SDG&E	(1,145)		(1,299)
SoCalGas:
Deferred income taxes recoverable in rates	113		44
Pension and other postretirement benefit plan obligations	39		51
Employee benefit costs	31		31
Removal obligations	(603)		(627)
Environmental costs	34		34
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(46)		(146)
Safety and reliability	425		339
Public purpose programs	(213)		(183)
Liability insurance premium	18		16
Other balancing accounts	125		42
Other regulatory assets, net(2)	153		142
Total SoCalGas	76		(257)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		77
Total Sempra	$	(992)	$	(1,479)

(1)    At June 30, 2022 and December 31, 2021, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $453 and $358, respectively, and for SoCalGas was $601 and $410, respectively.

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

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SEMPRA CALIFORNIA

CPUC GRC

The CPUC uses GRCs to set rates designed 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 are proposing post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 12% at SDG&E and approximately 6% to 8% at SoCalGas. SDG&E and SoCalGas have requested that the CPUC issue a final decision by the end of 2023 with new rates to be implemented in January 2024. SDG&E proposes to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in mid-2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole to have its cost of capital determined in lieu of the CCM.

Authorized Cost of Capital, Subject to the CCM

In December 2019, the CPUC approved the cost of capital (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index.

AUTHORIZED CPUC COST OF CAPITAL, SUBJECT TO THE CCM
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	%	4.59	%	2.08	%	Long-Term Debt	45.60	%	4.23	%	1.93	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.20		5.30		Common Equity	52.00		10.05		5.23
100.00	%			7.55	%		100.00	%			7.30	%

For the measurement period that ended September 30, 2021, the CCM would trigger for SDG&E if the CPUC determines that the CCM should be implemented because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event such that the CCM should not apply. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects to receive a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022.

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Proposed Cost of Capital

In April 2022, SDG&E and SoCalGas each filed applications with the CPUC to update their cost of capital (shown in the table below), which would become effective on January 1, 2023 and would remain in effect through December 31, 2025, subject to the CCM if it remains in place as proposed. SDG&E and SoCalGas expect to receive a final decision by the end of 2022.

PROPOSED CPUC COST OF CAPITAL
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
46.00	%	3.87	%	1.78	%	Long-Term Debt	45.60	%	3.89	%	1.77	%
—		—		—		Preferred Equity	0.40		6.00		0.02
54.00		10.55		5.70		Common Equity	54.00		10.75		5.81
100.00	%			7.48	%		100.00	%			7.60	%

SOCALGAS

OSCs – Energy Efficiency and Advocacy

In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. In February 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 became the final decision of the CPUC in March 2022.

In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, a CPUC commissioner issued an alternative decision finding that there were violations of certain legal principles and imposing a financial penalty of $150,000. The alternative decision was adopted by the CPUC as the final decision in April 2022.

NOTE 5. ACQUISITIONS AND DIVESTITURES

ACQUISITION

Sempra Infrastructure

ESJ

In March 2021, Sempra Infrastructure completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of $65 million (net of $14 million of acquired cash and cash equivalents) plus the assumption of $277 million in debt (including $94 million owed from ESJ to Sempra Infrastructure that eliminates upon consolidation). Sempra Infrastructure previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased Sempra Infrastructure’s ownership interest in ESJ from 50% to 100%. We accounted for this asset acquisition using a cost accumulation

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model whereby the cost of the acquisition and carrying value of our previously held interest in ESJ ($34 million) were allocated to assets acquired ($458 million) and liabilities assumed ($345 million) based on their relative fair values. ESJ owns a fully operating wind power generation facility with a nameplate capacity of 155 MW that is fully contracted by SDG&E under a long-term PPA. Sempra Infrastructure recorded a $190 million intangible asset for the relative fair value of the PPA that will be amortized over a period of 14 years against revenues. On January 15, 2022, ESJ completed construction and began commercial operation of a second wind power generation facility with a nameplate capacity of 108 MW that is also fully contracted by SDG&E under a long-term PPA.

NOTE 6. 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 12 for information on equity earnings and losses, both before and net of income tax, by segment. See Note 1 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.

We provide additional information concerning our equity method investments in Notes 5 and 6 of the Notes to Consolidated Financial Statements in the Annual Report.

SEMPRA TEXAS UTILITIES

Oncor Holdings

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

In the six months ended June 30, 2022 and 2021, Sempra contributed $171 million and $100 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $170 million and $162 million, respectively, to Sempra.

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Operating revenues	$	1,293	$	1,147	$	2,542	$	2,286
Operating expenses	(908)		(836)		(1,805)		(1,665)
Income from operations	385		311		737		621
Interest expense	(108)		(102)		(216)		(204)
Income tax expense	(52)		(34)		(94)		(70)
Net income	226		167		417		332
Noncontrolling interest held by Texas Transmission Investment LLC	(46)		(34)		(84)		(67)
Earnings attributable to Sempra(1)	180		133		333		265

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

SEMPRA INFRASTRUCTURE

Cameron LNG JV

In the six months ended June 30, 2022, Sempra Infrastructure contributed $10 million to Cameron LNG JV. In the six months ended June 30, 2022 and 2021, Cameron LNG JV distributed to Sempra Infrastructure $233 million and $378 million, respectively, of which $165 million relates to the distribution from Cameron LNG JV’s SDSRA that we discuss below.

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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 $21 million at June 30, 2022, 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 its 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, as amended on June 29, 2021, 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 will 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 will recognize 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 9). At June 30, 2022, the fair value of the Support Agreement was $16 million, of which $7 million is included in Other Current Assets and $9 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

ESJ

As we discuss in Note 5, in March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, Sempra Infrastructure owned 50% of ESJ and accounted for its interest as an equity method investment. In the six months ended June 30, 2021, ESJ distributed a $4 million return of investment to IEnova.

TAG

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

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NOTE 7. DEBT AND CREDIT FACILITIES

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

SHORT-TERM DEBT

Committed Lines of Credit

At June 30, 2022, Sempra had an aggregate capacity of $9.5 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.

COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2022
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	May 2024	$	3,185	$	(42)	$	—	$	3,143
Sempra	May 2024	1,250		—		—		1,250
SDG&E	May 2024	1,500		—		—		1,500
SoCalGas	May 2024	750		—		—		750
SI Partners	November 2024	1,000		—		(285)		715
IEnova	September 2023	350		—		(310)		40
IEnova	February 2024	1,500		—		—		1,500
Total		$	9,535	$	(42)	$	(595)	$	8,898

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At June 30, 2022, each entity was in compliance with this ratio under its respective credit facility.

SI Partners must maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in its credit facility) of no more than 5.25 to 1.00 as of the end of each quarter. At June 30, 2022, SI Partners was in compliance with this ratio.

Uncommitted Lines of Credit

In addition to our committed lines of credit, Sempra Infrastructure’s foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $570 million at June 30, 2022, which are generally used for working capital requirements. We reflect amounts outstanding under these uncommitted lines of credit before reductions of any unamortized discounts.

FOREIGN UNCOMMITTED LINES OF CREDIT
(Dollars and U.S. dollar equivalent in millions)
			June 30, 2022
Borrower	Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
IEnova	September 2022	U.S. dollars	$	250	$	(250)	$	—
ECA LNG Phase 1(1)	August 2023	U.S. dollars or Mexican pesos	200		(32)		168
IEnova(2)	October 2023	U.S. dollars	100		(36)		64
IEnova	October 2023	U.S. dollars or Mexican pesos	20		—		20
Total			$	570	$	(318)	$	252

(1)    In March 2022, the facility was amended to increase the borrowing capacity from $100 to $200.

(2)    Advances are due in full within 180 days of the disbursement date, which may be extended in increments of 180 days provided that no advance may have a maturity date that falls more than three years after the date of disbursement.

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Uncommitted Letters of Credit

Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At June 30, 2022, we had approximately $730 million in standby letters of credit outstanding under these agreements.

UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		June 30, 2022
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2023 to May 2023	$	15
SoCalGas	November 2022 to October 2023	20
Sempra Infrastructure	July 2022 to October 2043	525
Parent and other	September 2022 to June 2023	170
Total		$	730

Term Loan

In July 2022, SoCalGas entered into an $800 million, 364-day term loan agreement with a maturity date of July 6, 2023. SoCalGas may request one borrowing of up to $800 million through October 7, 2022. The borrowings will bear interest at benchmark rates plus 70 bps and are due in full upon maturity. The term loan provides SoCalGas with additional liquidity outside of its line of credit, which may include payment of a portion of the costs associated with civil litigation related to the Leak.

Weighted-Average Interest Rates

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

WEIGHTED-AVERAGE INTEREST RATES
	June 30, 2022		December 31, 2021
Sempra	2.70	%	0.60	%
SDG&E	—		0.65
SoCalGas	—		0.21

LONG-TERM DEBT

Sempra

In March 2022, we issued $750 million aggregate principal amount of 3.30% senior unsecured notes due in full upon maturity on April 1, 2025 and received proceeds of $745 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $500 million of 3.70% senior unsecured notes due in full upon maturity on April 1, 2029 and received proceeds of $494 million (net of debt discount, underwriting discounts and debt issuance costs of $6 million). Each series of the notes is redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. We used a portion of the net proceeds for general corporate purposes and repayment of commercial paper.

SDG&E

In February 2022, SDG&E entered into a $400 million, two-year term loan with a maturity date of February 18, 2024. SDG&E borrowed $200 million in the three months ended March 31, 2022 and an additional $200 million in the three months ended June 30, 2022. The borrowings bear interest at benchmark rates plus 62.5 bps and are due in full upon maturity. The margin is based on SDG&E’s long-term senior unsecured credit rating. SDG&E used the net proceeds for repayment of commercial paper and for general corporate purposes.

In March 2022, SDG&E issued $500 million aggregate principal amount of 3.00% first mortgage bonds due in full upon maturity on March 15, 2032 and received proceeds of $494 million (net of debt discount, underwriting discounts and debt issuance costs of $6 million), and $500 million aggregate principal amount of 3.70% first mortgage bonds due in full upon maturity on March 15, 2052 and received proceeds of $492 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). Each of 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 a portion of the net proceeds for repayment of commercial paper and its 364-day term loan

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and intends to use the remaining proceeds for capital expenditures and other general corporate purposes.

SoCalGas

In March 2022, SoCalGas issued $700 million aggregate principal amount of 2.95% senior unsecured notes due in full upon maturity on April 15, 2027 and received proceeds of $691 million (net of debt discount, underwriting discounts and debt issuance costs of $9 million). The notes are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SoCalGas used a portion of the net proceeds for repayment of commercial paper and intends to use the remaining proceeds for general corporate purposes, which may include payment of a portion of the costs relating to civil litigation pertaining to the Leak.

Sempra Infrastructure

SI Partners

In January 2022, SI Partners completed a private offering of $400 million in aggregate principal of 3.25% senior notes due in full upon maturity on January 15, 2032 to “qualified institutional buyers” as defined in Rule 144A under the Securities Act of 1933, as amended (the Securities Act), and non-U.S. persons outside the U.S. under Regulation S under the Securities Act. The notes are senior unsecured obligations that rank equally with all of SI Partners’ existing and future outstanding unsecured senior indebtedness and are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. Sempra Infrastructure received proceeds of $390 million (net of debt discount, underwriting discounts and debt issuance costs of $10 million). Sempra Infrastructure used the net proceeds for general corporate purposes, including the repayment of certain indebtedness of its subsidiaries.

ECA LNG Phase 1

In December 2020, ECA LNG Phase 1 entered into a five-year loan agreement with a syndicate of nine banks for an aggregate principal amount of up to $1.6 billion. Sempra and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest based on their proportionate ownership interest in ECA LNG Phase 1 of 83.4% and 16.6%, respectively. At June 30, 2022 and December 31, 2021, $455 million and $341 million, respectively, was outstanding under the loan agreement, with a weighted-average interest rate of 4.37% and 2.93%, respectively.

In July 2022, ECA LNG Phase 1 replaced Sempra with IEnova as the guarantor and replaced two of the nine banks and their combined principal commitment of $203 million ($61 million of which was outstanding at June 30, 2022) with a shareholder loan from IEnova, thereby reducing the syndicate to seven banks.

NOTE 8. 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 hedge termination costs on interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows.

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HEDGE ACCOUNTING

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

ENERGY DERIVATIVES

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

▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, 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 that have been filed with and approved by the CPUC. 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 Electric Fuel and Purchased Power or in Cost of Natural Gas.

▪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 their assets which support the following businesses: LNG, natural gas transportation 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. Certain of these derivatives may also be designated as cash flow hedges.

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

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	June 30, 2022	December 31, 2021
Sempra:
Natural gas	MMBtu	193	184
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SDG&E:
Natural gas	MMBtu	10	7
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SoCalGas:
Natural gas	MMBtu	141	201

INTEREST RATE DERIVATIVES

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

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

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INTEREST RATE DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	436	2022-2034	$	462	2022-2034

FOREIGN CURRENCY DERIVATIVES

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

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

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2022-2023	$	306	2022-2023
Other foreign currency derivatives	65		2022-2023	106		2022-2023

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.

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DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2022
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	5	$	27	$	—	$	—
Foreign exchange instruments	—		—		(2)		—
Interest rate and foreign exchange instruments	—		—		(117)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	182		91		(182)		(89)
Associated offsetting commodity contracts	(167)		(32)		167		32
Commodity contracts subject to rate recovery	27		25		(22)		(1)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		111		(153)		(58)
Additional cash collateral for commodity contracts not subject to rate recovery	76		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	48		—		—		—
Total(1)	$	168	$	111	$	(153)	$	(58)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	26	$	25	$	(14)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	23		25		(11)		—
Additional cash collateral for commodity contracts subject to rate recovery	36		—		—		—
Total(1)	$	59	$	25	$	(11)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	1	$	—	$	(8)	$	(1)
Net amounts presented on the balance sheet	1		—		(8)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	12		—		—		—
Total	$	13	$	—	$	(8)	$	(1)

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

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DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2021
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	6	$	(6)	$	(2)
Foreign exchange instruments	1		1		(1)		—
Interest rate and foreign exchange instruments	—		—		(1)		(130)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	136		11		(122)		(10)
Associated offsetting commodity contracts	(93)		(8)		93		8
Commodity contracts subject to rate recovery	38		52		(58)		—
Associated offsetting commodity contracts	(8)		—		8		—
Net amounts presented on the balance sheet	74		62		(87)		(134)
Additional cash collateral for commodity contracts not subject to rate recovery	58		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	46		—		—		—
Total(1)	$	178	$	62	$	(87)	$	(134)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	34	$	52	$	(20)	$	—
Associated offsetting commodity contracts	(5)		—		5		—
Net amounts presented on the balance sheet	29		52		(15)		—
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(1)	$	57	$	52	$	(15)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4	$	—	$	(38)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	1		—		(35)		—
Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total	$	19	$	—	$	(35)	$	—

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

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

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	13	$	(6)	Interest Expense	$	—	$	1
Interest rate instruments	50		(32)		Equity Earnings(1)	(13)		(19)
Foreign exchange instruments	—		(1)		Revenues: Energy- Related Businesses	1		—
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	—		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	4		7		Interest Expense	1		—
					Other (Expense) Income, Net	—		7
Total	$	67	$	(33)		$	(12)	$	(11)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	—
	Six months ended June 30,					Six months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	35	$	20	Interest Expense	$	1	$	(1)
Interest rate instruments	144		51		Equity Earnings(1)	(27)		(38)
Foreign exchange instruments	(3)		2		Revenues: Energy- Related Businesses	2		(1)
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	(2)		2		Equity Earnings(1)	1		(1)
Interest rate and foreign exchange instruments	13		1		Interest Expense	1		—
					Other (Expense) Income, Net	6		1
Total	$	187	$	76		$	(17)	$	(40)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	—

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

For Sempra, we expect that net gains before NCI of $6 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $11 million attributable to NCI) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at June 30, 2022 is approximately 12 years for Sempra. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 17 years.

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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 (loss) gain on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2022		2021		2022		2021
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(151)	$	(142)	$	(228)	$	(190)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(4)		—		(4)		2
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	(24)		41		(6)		43
Foreign exchange instruments	Other (Expense) Income, Net	—		—		—		(24)
Total		$	(179)	$	(101)	$	(238)	$	(169)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	(24)	$	41	$	(6)	$	43
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(4)	$	—	$	(4)	$	2

CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at June 30, 2022 and December 31, 2021 was $17 million and $88 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at June 30, 2022 and December 31, 2021 was $9 million and $36 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at June 30, 2022 or December 31, 2021. At June 30, 2022, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $17 million and $9 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.

NOTE 9. FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2022 and December 31, 2021. 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, 2021.

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The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 8 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 derivatives 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 6, 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.”

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RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Short-term investments held in Rabbi Trust	50		—		—		50
Interest rate instruments	—		32		—		32
Commodity contracts not subject to rate recovery	—		74		—		74
Effect of netting and allocation of collateral(2)	76		—		—		76
Commodity contracts subject to rate recovery	13		1		35		49
Effect of netting and allocation of collateral(2)	32		10		6		48
Support Agreement, net of related guarantee fees	—		—		16		16
Total	$	499	$	665	$	57	$	1,221
Liabilities:
Foreign exchange instruments	$	—	$	2	$	—	$	2
Interest rate and foreign exchange instruments	—		117		—		117
Commodity contracts not subject to rate recovery	—		72		—		72
Commodity contracts subject to rate recovery	—		18		2		20
Total	$	—	$	209	$	2	$	211

(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.

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RECURRING FAIR VALUE MEASURES – SEMPRA (CONTINUED)
(Dollars in millions)
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Short-term investments held in Rabbi Trust	81		—		—		81
Interest rate instruments	—		6		—		6
Foreign exchange instruments	—		2		—		2
Commodity contracts not subject to rate recovery	—		46		—		46
Effect of netting and allocation of collateral(2)	58		—		—		58
Commodity contracts subject to rate recovery	12		1		69		82
Effect of netting and allocation of collateral(2)	31		9		6		46
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	601	$	649	$	82	$	1,332
Liabilities:
Interest rate instruments	$	—	$	8	$	—	$	8
Foreign exchange instruments	—		1		—		1
Interest rate and foreign exchange instruments	—		131		—		131
Commodity contracts not subject to rate recovery	—		31		—		31
Commodity contracts subject to rate recovery	—		35		15		50
Total	$	—	$	206	$	15	$	221

(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.

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RECURRING FAIR VALUE MEASURES – SDG&E
(Dollars in millions)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Commodity contracts subject to rate recovery	13		—		35		48
Effect of netting and allocation of collateral(2)	30		—		6		36
Total	$	371	$	548	$	41	$	960
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	2	$	11
Total	$	—	$	9	$	2	$	11
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Commodity contracts subject to rate recovery	12		—		69		81
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	453	$	585	$	75	$	1,113
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	15	$	15
Total	$	—	$	—	$	15	$	15

(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.

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RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	2		10		—		12
Total	$	2	$	11	$	—	$	13
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	—	$	9
Total	$	—	$	9	$	—	$	9
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	9		9		—		18
Total	$	9	$	10	$	—	$	19
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	35	$	—	$	35
Total	$	—	$	35	$	—	$	35

(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 June 30,
	2022		2021
Balance at April 1	$	58	$	62
Realized and unrealized (losses) gains	(30)		8
Allocated transmission instruments	(6)		(2)
Settlements	11		12
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(23)	$	14
	Six months ended June 30,
	2022		2021
Balance at January 1	$	54	$	69
Realized and unrealized (losses) gains	(23)		6
Allocated transmission instruments	(6)		(2)
Settlements	8		7
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(18)	$	12

(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. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments.

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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
2022	$	(3.67)	to	$	6.96	$	(0.70)
2021	(1.81)		to	14.11		(0.12)

The impact associated with discounting is negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a significantly higher (lower) fair value measurement. We summarize CRR volumes in Note 8.

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

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2022	$	25.25	to	$	125.00	$	66.36
2021		22.45	to		151.90		49.27

A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 8.

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.

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LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2022		2021
Balance at April 1	$	12	$	3
Realized and unrealized gains(1)	6		3
Settlements	(2)		(2)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	5	$	2
	Six months ended June 30,
	2022		2021
Balance at January 1	$	7	$	3
Realized and unrealized gains(1)	14		5
Settlements	(5)		(4)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	13	$	4

(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 $9 in Other Long-term Assets at June 30, 2022 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.

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FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2022
Sempra:
Short-term amounts due from unconsolidated affiliates(1)	$	626	$	—	$	630	$	—	$	630
Long-term note receivable(2)	310		—		—		278		278
Long-term amounts due to unconsolidated affiliates	282		—		251		—		251
Total long-term debt(3)	23,924		—		21,709		—		21,709
SDG&E:
Total long-term debt(4)	$	7,800	$	—	$	7,102	$	—	$	7,102
SoCalGas:
Total long-term debt(5)	$	5,459	$	—	$	5,110	$	—	$	5,110
	December 31, 2021
Sempra:
Long-term note receivable(2)	$	300	$	—	$	—	$	327	$	327
Long-term amounts due from unconsolidated affiliates(1)	640		—		642		—		642
Long-term amounts due to unconsolidated affiliates	287		—		295		—		295
Total long-term debt(3)	20,099		—		22,126		—		22,126
SDG&E:
Total long-term debt(4)	$	6,417	$	—	$	7,236	$	—	$	7,236
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,367	$	—	$	5,367

(1)    Before allowances for credit losses of $1 at December 31, 2021. Includes $1 and $2 of accrued interest receivable at June 30, 2022 and December 31, 2021, respectively, in Due From Unconsolidated Affiliates – Current.

(2)    Before allowances for credit losses of $7 and $8 at June 30, 2022 and December 31, 2021, respectively. Excludes unamortized transaction costs of $5 at both June 30, 2022 and December 31, 2021, respectively.

(3)    Before reductions of unamortized discount and debt issuance costs of $294 and $260 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,334 and $1,335 at June 30, 2022 and December 31, 2021, respectively.

(4)    Before reductions of unamortized discount and debt issuance costs of $73 and $61 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,266 and $1,274 at June 30, 2022 and December 31, 2021, respectively.

(5)    Before reductions of unamortized discount and debt issuance costs of $43 and $36 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $68 and $61 at June 30, 2022 and December 31, 2021, respectively.

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

NOTE 10. SAN ONOFRE NUCLEAR GENERATING STATION

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

NUCLEAR DECOMMISSIONING AND FUNDING

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost.

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The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the Samuel Lawrence Foundation filed a notice of appeal. To date, decommissioning work has not been interrupted as a result of this writ petition.

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 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 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 9.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	43	$	1	$	(1)	$	43
Municipal bonds(2)	305		1		(13)		293
Other securities(3)	256		1		(20)		237
Total debt securities	604		3		(34)		573
Equity securities	109		187		(8)		288
Short-term investments, primarily cash equivalents	15		—		—		15
Receivables (payables), net	(13)		—		—		(13)
Total	$	715	$	190	$	(42)	$	863
	December 31, 2021
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	56	$	—	$	—	$	56
Municipal bonds	309		13		(1)		321
Other securities	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012

(1)    Maturity dates are 2023-2052.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2022-2072.

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

SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Proceeds from sales	$	155	$	254	$	397	$	542
Gross realized gains	3		18		14		39
Gross realized losses	(7)		(1)		(11)		(3)

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

SDG&E’s ARO related to decommissioning costs for SONGS Units 1, 2 and 3 was $557 million at June 30, 2022 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

NUCLEAR INSURANCE

The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.1 million of retrospective premiums based on overall member claims.

NOTE 11. COMMITMENTS AND CONTINGENCIES

LEGAL PROCEEDINGS

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

At June 30, 2022, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $2,118 million for Sempra, including $13 million for SDG&E and $2,029 million for SoCalGas. Amounts for Sempra and SoCalGas include $2,004 million for matters related to the Leak, which we discuss below.

SoCalGas

Aliso Canyon Natural Gas Storage Facility Gas Leak

From October 23, 2015 through February 11, 2016, SoCalGas experienced a natural gas leak from one of the injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility in Los Angeles County. As described below, numerous lawsuits, investigations and regulatory proceedings have been initiated in response to the Leak, resulting in significant costs, which together with other Leak-related costs are discussed below in “Cost Estimate, Accounting Impact and Insurance.”

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Civil Litigation – Litigation Subject to Agreements to Resolve. As of August 1, 2022, approximately 390 lawsuits including approximately 36,000 plaintiffs (the Individual Plaintiffs) were pending against SoCalGas and Sempra related to the Leak. All these cases are coordinated before a single court in the LA Superior Court for pretrial management.

In November 2017, in the coordinated proceeding, a Third Amended Consolidated Master Case Complaint for Individual Actions was filed on behalf of the Individual Plaintiffs, through which their separate lawsuits are managed for pretrial purposes. The consolidated complaint asserts causes of action for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment, loss of consortium and wrongful death against SoCalGas and Sempra (the Individual Plaintiff Litigation). The complaint also asserted violations of Proposition 65, which were resolved in January 2022. The consolidated complaint seeks compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, injunctive relief, costs of future medical monitoring, civil penalties, and attorneys’ fees.

In October 2018 and January 2019, complaints were filed on behalf of 51 firefighters stationed near the Aliso Canyon natural gas storage facility who allege they were injured by exposure to chemicals released during the Leak. The complaints against SoCalGas and Sempra assert causes of actions for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment and loss of consortium. The complaints seek compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, and attorneys’ fees. These complaints are included in the coordinated proceeding and the Individual Plaintiff Litigation.

In September 2021, SoCalGas and Sempra entered into an agreement with counsel representing over 80% of the plaintiffs in the Individual Plaintiff Litigation to resolve the claims of all Individual Plaintiffs for a payment of up to $1.8 billion. The agreement is subject to acceptance by no fewer than roughly 97% of all plaintiffs in the Individual Plaintiff Litigation. The agreement, which requires each plaintiff who accepts a settlement to release all such plaintiff’s claims against SoCalGas, Sempra and their respective affiliates related to the Individual Plaintiff Litigation and the Leak, provides that the settlement amount will be reduced based on the number of plaintiffs who do not accept. The LA Superior Court previously approved the process to allocate payments among the plaintiffs. The Individual Plaintiffs’ counsel report that they have exceeded the 97% threshold described above and, in July 2022, the parties extended the date by which all conditions under the agreement must be met by the Individual Plaintiffs’ counsel or waived by SoCalGas and Sempra. SoCalGas expects to make a payment of approximately $1.8 billion under the agreement on or around August 30, 2022. The plaintiffs who do not agree to participate in the settlement will be able to continue to pursue their claims. Pursuant to the agreement, the Individual Plaintiff Litigation has been stayed.

In January 2017, a putative class of persons and businesses who own or lease real property within a five-mile radius of the well filed a consolidated class action complaint against SoCalGas and Sempra (the Property Class Action). The Property Class Action asserts claims for strict liability for ultra-hazardous activities, negligence, negligence per se, violation of the California Unfair Competition Law, trespass, permanent and continuing public and private nuisance, and inverse condemnation.

In September 2021, SoCalGas and Sempra entered into an agreement to settle the Property Class Action for a total amount of $40 million. In April 2022, the LA Superior Court gave final approval of the settlement, which releases SoCalGas, Sempra and their respective affiliates from all claims of the property class members.

Complaints on behalf of five property developers (the Developer Plaintiffs) were filed in October 2018 and October 2020 against SoCalGas and Sempra alleging causes of action for strict liability, negligence per se, negligence, negligent interference, continuing nuisance, permanent nuisance, inverse condemnation and violation of the California Unfair Competition Law and California Public Utilities Code section 2106. The complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In January 2022 and March 2022, SoCalGas and Sempra entered into agreements to settle the claims of four of the Developer Plaintiffs.

Civil Litigation – Unresolved Litigation. The complaint of one of the Developer Plaintiffs remains pending, and the LA Superior Court has scheduled a trial for October 2022. SoCalGas has engaged in settlement discussions with the remaining Developer Plaintiff.

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 actions were joined in an Amended Consolidated Shareholder Derivative Complaint, which was dismissed with prejudice in January 2021. The plaintiffs have appealed this dismissal. In the remaining fourth action, the plaintiffs filed an amended complaint in June 2022.

An adverse ruling in any of the lawsuits by plaintiffs in the Individual Plaintiff Litigation who do not agree to settle or by the remaining Developer Plaintiff could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial

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condition, cash flows and/or prospects. In addition, there can be no assurance that the conditions to resolve the Individual Plaintiff Litigation will be satisfied or waived to the extent not satisfied.

Regulatory Proceedings. In January 2016, CalGEM and the CPUC directed an independent analysis of the technical root cause of the Leak to be conducted by Blade. In May 2019, Blade released its report, which concluded that the Leak was caused by a failure of the production casing of the well due to corrosion and that attempts to stop the Leak were not effectively conducted, but did not identify any instances of non-compliance by SoCalGas. Blade concluded that SoCalGas’ compliance activities conducted prior to the Leak did not find indications of a casing integrity issue. Blade opined, however, that there were measures, none of which were required by gas storage regulations at the time, that could have been taken to aid in the early identification of corrosion and that, in Blade’s opinion, would have prevented or mitigated the Leak. The report also identified well safety practices and regulations that have since been adopted by CalGEM and implemented by SoCalGas.

In June 2019, the CPUC opened an OII to consider penalties against SoCalGas for the Leak, which it later bifurcated into two phases. The first phase will consider whether SoCalGas violated California Public Utilities Code Section 451 or other laws, CPUC orders or decisions, rules or requirements, whether SoCalGas engaged in unreasonable and/or imprudent practices with respect to its operation and maintenance of the Aliso Canyon natural gas storage facility or its related record-keeping practices, whether SoCalGas cooperated sufficiently with the SED of the CPUC and Blade during the pre-formal investigation, and whether any of the mitigation measures proposed by Blade should be implemented to the extent not already done. The SED, based largely on the Blade report, has alleged a total of 324 violations in the first phase, asserting that SoCalGas violated California Public Utilities Code Section 451 and failed to cooperate in the investigation and to keep proper records. Hearings on a subset of issues began in March 2021. A schedule for hearings on the remaining issues has not been set. The second phase will consider 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 the SED as determined by the CPUC in the first phase. In addition, the second phase will determine the amounts of various costs incurred by SoCalGas and other parties in connection with the Leak and the ratemaking treatment or other disposition of such costs, which could result in little or no recovery of such costs by SoCalGas. SoCalGas has engaged in settlement discussions with the SED in connection with this proceeding.

In February 2017, the CPUC opened a proceeding pursuant to the SB 380 OII to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility while still maintaining energy and electric reliability for the region, but excluding issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. The first phase of the proceeding established a framework for the hydraulic, production cost and economic modeling assumptions for the potential reduction in usage or elimination of the Aliso Canyon natural gas storage facility. Phase 2 of the proceeding, which is evaluating the impacts of reducing or eliminating the Aliso Canyon natural gas storage facility using the established framework and models, began in the first quarter of 2019. In December 2019, the CPUC added a third phase of the proceeding and engaged a consultant who is analyzing alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2035 timeframe. In July 2021, the CPUC combined Phase 2 and Phase 3 and modified the scope of Phase 3 to also address potential implementation of alternatives to the Aliso Canyon natural gas storage facility if the CPUC determines that the Aliso Canyon natural gas storage facility should be permanently closed. The CPUC also added all California IOUs as parties to the proceeding and encouraged all load serving entities in the Los Angeles Basin to join the proceeding.

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

At June 30, 2022, the Aliso Canyon natural gas storage facility had a net book value of $908 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, incur higher than expected operating costs and/or be required to make additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Any such outcome could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Cost Estimate, Accounting Impact and Insurance. SoCalGas has incurred significant costs related to the Leak, primarily for temporary relocation of community residents; to control the well and stop the Leak; to mitigate the natural gas released; to purchase natural gas to replace what was lost through the Leak; to defend against and, in certain cases, settle, civil and criminal litigation arising from the Leak; to pay the costs of the government-ordered response to the Leak, including the costs for Blade to conduct the root cause analysis described above; to respond to various government and agency investigations regarding the Leak; and to comply with increased regulation imposed as a result of the Leak. At June 30, 2022, SoCalGas estimates these costs related

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to the Leak are $3,361 million (the cost estimate), which includes $1,279 million of costs recovered or probable of recovery from insurance. This cost estimate may increase significantly as more information becomes available. At June 30, 2022, $2,003 million of the cost estimate is accrued in Reserve for Aliso Canyon Costs and $4 million of the cost estimate is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets.

In the three months and six months ended June 30, 2022, SoCalGas recorded total charges of $45 million ($32 million after tax) and $137 million ($98 million after tax), respectively, inclusive of estimated legal costs, in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Condensed Consolidated Statements of Operations related to the claims of the Developer Plaintiffs that we describe above. These charges are included in the cost estimate that we describe above.

Except for the amounts paid or estimated to settle certain legal and regulatory matters as described above, the cost estimate does not include (i) any amounts necessary to resolve claims of Individual Plaintiffs who do not agree to participate in the settlement of the Individual Plaintiff Litigation or (ii) the matters that we describe above in “Civil Litigation – Unresolved Litigation” and “Regulatory Proceedings” 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 for damages, restitution, civil or administrative fines or penalties, defense, settlement or other costs or remedies that may be imposed or incurred. The cost estimate also does not include certain other costs incurred by Sempra associated with defending against shareholder derivative lawsuits and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued. The costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

We have received insurance payments for many of the categories of costs included in the cost estimate, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response to the Leak, certain legal costs and lost gas. At June 30, 2022, we recorded the expected recovery of the cost estimate related to the Leak of $344 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. This amount is exclusive of insurance retentions and $935 million of insurance proceeds we received through June 30, 2022. We intend to pursue the full extent of our insurance coverage for the costs we have incurred. Other than insurance for certain future defense costs we may incur as well as directors’ and officers’ liability, we have exhausted all of our insurance in 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. If we are not able to secure additional insurance recovery, if any costs we have recorded as an insurance receivable are not collected, if there are delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts and/or delays could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Sempra Infrastructure

Energía Costa Azul

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

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

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

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

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In addition, four cases involving two adjacent areas of real property on which part of the ECA Regas Facility is situated, each brought by a single plaintiff or her descendants, remain pending against the facility, as follows:

▪The first disputed area is subject to a claim in the federal Agrarian Court that has been ongoing since 2006, 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 final federal appeal against the appellate court ruling. A final ruling from the Federal Collegiate Circuit Court is pending.

▪The second disputed area is a parcel adjacent to the ECA Regas Facility that allegedly overlaps with land on which the ECA Regas Facility is situated, which is subject to a claim in the federal Agrarian Court and two claims in Mexican civil courts. The ECA Regas Facility first bought the property from the federal government in 2003; however, to resolve an ownership controversy, in 2008, the ECA Regas Facility reached a financial settlement with the plaintiff to eliminate an adverse claim to its title. Nevertheless, the plaintiff sued in 2013 for the nullity of both titles. The Agrarian Court ruled in favor of the plaintiff in May 2021, nullifying the first property title. Sempra Infrastructure appealed the ruling in July 2021. In May 2022, Sempra Infrastructure won the appeal and the plaintiff’s claims were dismissed, which the plaintiff has appealed. The ECA Regas Facility continues to hold the second property title to the land. The two civil court proceedings, which seek to invalidate the contract by which the ECA Regas Facility purchased for the second time the applicable parcel of land on which the ECA Regas Facility is situated on the grounds that the purchase price was allegedly unfair, are progressing at different stages. In the first civil case, initiated in 2013, the court ruled in favor of the ECA Regas Facility, and the final decision was affirmed on a federal appeal. The descendants of the same plaintiff filed the second civil case in 2019, which was dismissed by the court. However, the dismissal has been appealed, which is pending the appellate court’s ruling. In April 2022, the ECA Regas Facility entered into a settlement agreement with the plaintiff, whereby the plaintiff has agreed to recognize the ECA Regas Facility as the sole owner of the property and waive any current or future rights over the property, or any other properties related to the ECA Regas Facility. The settlement agreement is pending court approval and would definitively resolve all three pending cases.

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

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

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

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

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

Customer Dispute. In May 2020, the two third-party capacity customers at the ECA Regas Facility, Shell Mexico and Gazprom, asserted that a 2019 update of the general terms and conditions for service at the facility, as approved by the CRE, resulted in a breach of contract by Sempra Infrastructure and a force majeure event. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and Gazprom joined the proceeding, and a hearing was held in October 2021. The International Court of Arbitration issued a final, non-appealable decision dated April 27, 2022 in favor of Sempra Infrastructure dismissing all claims and confirming the contracts remain in force. Shell Mexico submitted a request to the International Court of Arbitration, and Gazprom joined the request, to issue an additional decision, asserting that two of the claims were not addressed in the ruling. Sempra Infrastructure filed a response and requested that any additional decision by the International Court of Arbitration be incorporated into the original decision as one, final ruling for clarity to aid in enforcement proceedings should they become necessary.

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Citing the alleged breach, Shell Mexico stopped making payments under its LNG storage and regasification agreement. Due to nonpayment, Sempra Infrastructure drew against Shell Mexico’s letters of credit provided as payment security until they were fully exhausted in March 2022 and this customer has not resumed making payments. Although Gazprom had previously been making regular monthly payments under its LNG storage and regasification agreement, Sempra Infrastructure drew against and fully exhausted Gazprom’s letters of credit in April 2022 due to Gazprom’s non-renewal of such letters of credit as required under the agreement. Gazprom has not paid its invoices since March 2022, so funds drawn from the letters of credit have been used to fully offset such nonpayment. We expect that these funds will provide payment security from Gazprom through the end of 2024.

In addition to the arbitration proceeding, Shell Mexico also filed constitutional claims against the CRE’s approval of the general terms and conditions for service at the facility and against the issuance of the liquefaction permit. Shell Mexico’s request for an injunction against the general terms and conditions was denied, and the ruling was upheld on appeal. The request for an injunction against the liquefaction permit was denied, and the decision was vacated and remanded on appeal to the First District Court in Administrative Matters, which again denied the injunction. The case on the injunction request was then heard again by the appellate court. A hearing was held on the merits and a decision is pending.

Sonora Pipeline

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

Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 2017 and, as a result, Sempra Infrastructure declared a force majeure event. In 2017, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory, which has prevented Sempra Infrastructure from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of Sempra Infrastructure and held that the Yaqui tribe was properly consulted and that consent from the Yaqui tribe was properly received. Representatives of the Bácum community appealed this decision, causing the suspension order preventing Sempra Infrastructure from repairing the damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory to remain in place until the appeals process is exhausted. In December 2021, the court of appeals referred the matter to Mexico’s Supreme Court. In June 2022, the Supreme Court remanded the case back to the court of appeals for final resolution.

Sempra Infrastructure exercised its rights under the contract, which included seeking force majeure payments for the two-year period such force majeure payments were required to be made, which ended in August 2019.

In July 2019, the CFE filed a request for arbitration generally to nullify certain contract terms that provide for fixed capacity payments in instances of force majeure and made a demand for substantial damages in connection with the force majeure event. In September 2019, the arbitration process ended when Sempra Infrastructure and the CFE reached an agreement to restart natural gas transportation service on the earlier of completion of repair of the damaged pipeline or January 15, 2020, and to modify the tariff structure and extend the term of the contract by 10 years. Subsequently, Sempra Infrastructure and the CFE agreed to extend the service start date multiple times, most recently to November 30, 2022. Under the revised agreement, the CFE will resume making payments only when the damaged section of the Guaymas-El Oro segment of the Sonora pipeline is repaired. If the pipeline is not repaired by November 30, 2022, and 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. Discussions with the CFE regarding the future of the pipeline are underway in accordance with a non-binding MOU announced in January 2022 that, among other matters, addresses efforts to restart service on the pipeline. In July 2022, Sempra Infrastructure and the CFE entered into a Shareholders’ Agreement that establishes a framework for a JV between the parties to work on restarting service on the pipeline, including the potential re-routing of a portion of the pipeline. This agreement is subject to a number of conditions to be satisfied before it becomes effective, including regulatory and corporate authorizations.

At June 30, 2022, Sempra Infrastructure had $426 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if Sempra Infrastructure is unable to make such repairs (which have not

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commenced) or re-route a portion of the pipeline (which has not been agreed to by the parties, but is subject to negotiation pursuant to a non-binding MOU and a Shareholders’ Agreement, as described above) and resume operations or if Sempra Infrastructure terminates the contract and is unable to obtain recovery, which in each case could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Sasabe-Puerto Libertad-Guaymas Segment. In June 2014, Sempra Infrastructure and a landowner agreed to enter into a voluntary right-of-way easement agreement for the construction and operation of a seven-mile section of the 314-mile Sasabe-Puerto Libertad-Guaymas segment of the Sonora natural gas pipeline on the landowner’s property. However, in 2015, the landowner filed a complaint demanding the easement agreement be nullified. In September 2021, a definitive and non-appealable judgment was issued declaring the easement agreement nullified and ordering the removal of the pipeline from the landowner’s property. The execution of the judgment is suspended as a result of an amparo lawsuit filed by the CFE as an interested third party that did not participate in the litigation. Sempra Infrastructure filed a special judicial action asking the civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. In July 2022, Sempra Infrastructure and the landowner entered into a new easement agreement approved by the court for the seven-mile section on the landowner’s property, thus bringing this case to definitive conclusion.

Regulatory and Other Actions by the Mexican Government

We describe below certain actions by the Mexican government that could have a material impact on the energy sector in Mexico. Sempra Infrastructure and other parties affected by these resolutions, orders, decrees, regulations and proposed amendments to Mexican law have challenged them by filing amparo and other claims, some of which have been granted injunctive relief. The court-ordered injunctions or suspensions provide temporary relief until Mexico’s federal district court or Supreme Court ultimately resolves the amparo and other claims. An unfavorable decision on one or more of these amparo or other challenges or the potential for extended disputes may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, may result in decreased revenues and cash flows, and may negatively impact our ability to recover the carrying values of our investments in Mexico, any of which may have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects.

Transmission Rates for Legacy Generation Facilities. In May 2020, the CRE approved an update to the transmission rates included in legacy renewable and cogeneration energy contracts based on the claim that the legacy transmission rates did not reflect fair and proportional costs for providing the applicable services and, therefore, created inequitable competitive conditions. Three of Sempra Infrastructure’s renewable energy facilities (Don Diego Solar, Border Solar and Ventika) are currently holders of contracts with such legacy rates, and under the terms of these contracts any increases in the transmission rates would be passed through directly to their customers. These renewable energy facilities sought and obtained injunctive relief but were required to guarantee the difference in tariffs. The three facilities obtained favorable resolutions from a lower court and the CRE appealed those decisions, which were definitively affirmed in favor of the Don Diego Solar, Border Solar and Ventika facilities, whereby the injunctions were made permanent, the regulations were declared unconstitutional, and the guarantee was determined to not be required. The resolution is definitive and final.

Offtakers of Legacy Generation Permits. In October 2020, the CRE approved a resolution to amend the rules for the inclusion of new offtakers of legacy generation and self-supply permits (the Offtaker Resolution), which became effective immediately. The Offtaker Resolution prohibits self-supply permit holders from adding new offtakers that were not included in the original development or expansion plans, making modifications to the amount of energy allocated to the named offtakers, and including load centers that have entered into a supply arrangement under Mexico’s Electricity Industry Law. Don Diego Solar, Border Solar and Ventika are holders of self-supply permits and are impacted by the Offtaker Resolution. In January 2022, Don Diego Solar and Border Solar obtained a favorable resolution from a Mexican federal district court and the CRE appealed that decision. If Sempra Infrastructure is not able to obtain legal protection for these impacted facilities, Sempra Infrastructure expects it will sell Border Solar’s capacity and a portion of Don Diego Solar’s capacity affected by the Offtaker Resolution into the spot market. Currently, prices in the spot market are higher than the fixed prices in the PPAs that were entered into through self-supply permits, but these markets are subject to significant volatility. At June 30, 2022, Sempra Infrastructure had $14 million in other intangible assets, net, related to these self-supply permits previously granted by the CRE and impacted by the Offtaker Resolution that could be subject to impairment if Sempra Infrastructure is unable to obtain adequate legal protection. Sempra Infrastructure has filed lawsuits against the Offtaker Resolution and received injunctive relief pending final resolution.

Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective on March 10, 2021, and SENER, the CRE and CENACE were to have 180 calendar days to modify, as necessary, all resolutions,

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policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. However, a Mexican court issued a suspension of the amendments on March 19, 2021. In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law, but the qualified majority of eight votes out of 11 as is required in matters involving constitutionality was not reached and the proceeding was dismissed, which means that the Mexican Supreme Court did not issue a binding precedent and the amended Electricity Industry Law remains in force. Sempra Infrastructure filed three lawsuits against the amendments to the Electricity Industry Law and, in each of them, Sempra Infrastructure obtained a favorable judgment of the first instance in the lower courts, which has been appealed. If the proposed amendments are affirmed by the lower courts or by the Mexican Supreme Court (which in these cases would only require a simple majority vote), the CRE may be required to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, under a legal standard that is ambiguous and not well defined under the law.

Amendments to Mexico’s Hydrocarbons Law. In May 2021, amendments to Mexico’s Hydrocarbons Law were published and became effective. The amendments grant SENER and the CRE additional powers to suspend and revoke permits related to the midstream and downstream sectors. Suspension of permits will be determined by SENER or the CRE when a danger to national security, energy security, or to the national economy is foreseen. Likewise, new grounds for the revocation of permits are in place if the permit holder (i) carries out its activity with illegally imported products; (ii) fails, on more than one occasion, to comply with the provisions applicable to quantity, quality and measurement of the products; or (iii) modifies the technical conditions of its infrastructure without authorization. Additionally, in the case of existing permits, authorities will revoke those permits that fail to comply with the minimum storage requirements established by SENER or fail to comply with requirements or violate provisions established by the amended Hydrocarbons Law. All the Sempra Infrastructure entities participating in the Mexico hydrocarbons sector filed lawsuits against the initiative to reform the Hydrocarbons Law. In 2021, district courts issued judgments that the amendments do not affect the interests of the companies at this time and, as a result, dismissed the amparo lawsuits, including the lawsuits filed by Sempra Infrastructure entities. The Sempra Infrastructure entities have appealed these judgments. The Circuit Courts upheld the dismissal of the amparo lawsuits, except one that is pending resolution.

Proposed Constitutional Reform in Mexico. In September 2021, the President of Mexico presented a constitutional reform initiative with the stated goal of preserving energy security and self-sufficiency, and a continuous supply of electricity to the country’s population, as a condition for guaranteeing national security and the human right to a decent life. The CRE and the National Commission of Hydrocarbons would be dissolved, and their functions would be carried out by SENER. CENACE would be reinstated to the CFE, and the CFE would be responsible for generating, conducting, transforming, distributing and supplying electricity, and would be the only entity allowed to commercialize electric energy in Mexico. Electricity generation permits and contracts for the sale of electricity and RECs to the CFE, including permits at all of Sempra Infrastructure’s operational power generation facilities, would be canceled. The public electricity supply service would be provided exclusively by the CFE, which may acquire up to 46% of required energy from the private sector. Only certain private power plants would be permitted to continue generating electricity and compete to offer the CFE the lowest production costs. On April 17, 2022, the Chamber of Deputies in Mexico rejected the proposed constitutional reform.

Other Litigation

RBS Sempra Commodities

Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against RBS (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE, a subsidiary of RBS Sempra Commodities. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million (approximately $55 million in U.S. dollars at June 30, 2022), 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 June 30, 2022) 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

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Group, Ltd. has sought indemnity for the claim, and J.P. Morgan Chase & Co. has in turn sought indemnity from Sempra and RBS.

In the second quarter of 2021, we reduced our estimate of our obligations to settle pending VAT matters and related legal costs by $50 million in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations based on the settlement with Her Majesty’s Revenue and Customs (U.K.’s Revenue and Customs Department) on the First-Tier Tribunal case and revised assumptions on the High Court of Justice case.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of August 1, 2022, one lawsuit is pending. Additionally, in connection with the EFH bankruptcy proceeding, approximately 28,000 proofs of claim were filed on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding. The costs to defend or resolve these lawsuits and the amount of damages that may be imposed or incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Ordinary Course Litigation

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

LEASES

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

Lessee Accounting

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

Leases That Have Not Yet Commenced

SDG&E has entered into three energy storage tolling agreements, of which SDG&E expects two will commence in the third quarter of 2022 and one will commence in the second quarter of 2023. SDG&E expects the future minimum lease payments to be $7 million in 2022, $18 million in each of 2023 through 2026 and $101 million thereafter until expiration at various dates from 2032 through 2033.

SoCalGas has entered into a fleet vehicle agreement, under which SoCalGas expects leases will commence in the second half of 2022 through the first half of 2023. SoCalGas expects the future minimum lease payments to be $2 million in each of 2023 through 2026 and $10 million thereafter until expiration at various dates from 2030 through 2031.

Lessor Accounting

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

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

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LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sales-type leases:
Interest income	$	2	$	—	$	4	$	—
Total revenues from sales-type leases(1)	$	2	$	—	$	4	$	—
Operating leases:
Fixed lease payments	$	70	$	59	$	140	$	112
Variable lease payments	3		1		4		1
Total revenues from operating leases(1)	$	73	$	60	$	144	$	113
Depreciation expense	$	14	$	12	$	27	$	22

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first six months of 2022 to contractual commitments discussed in Notes 1 and 16 of the Notes to Consolidated Financial Statements in the Annual Report.

LNG Purchase Agreement

Sempra Infrastructure has a 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 2022 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At June 30, 2022, we expect the commitment amount to decrease by $208 million in 2022 and then increase by $227 million in 2023, $203 million in 2024, $191 million in 2025, $175 million in 2026 and by $421 million thereafter (through contract termination in 2029) compared to December 31, 2021, reflecting changes in estimated forward prices since December 31, 2021 and actual transactions for the first six months of 2022. These LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted, under the agreement are delivered. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amount provided under the agreement due to the customer electing to divert cargoes as allowed by the agreement.

ENVIRONMENTAL ISSUES

We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $59 million for Sempra, $18 million for SDG&E and $15 million for SoCalGas at June 30, 2022.

NOTE 12. 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 electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, 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. Sempra Infrastructure owns a 70% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at June 30, 2022.

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

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

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

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SEGMENT INFORMATION
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
REVENUES
SDG&E	$	1,399	$	1,318	$	2,844	$	2,655
SoCalGas	1,501		1,124		3,494		2,632
Sempra Infrastructure	689		341		1,113		790
All other	—		1		—		2
Adjustments and eliminations	(2)		(1)		—		(1)
Intersegment revenues(1)	(40)		(42)		(84)		(78)
Total	$	3,547	$	2,741	$	7,367	$	6,000
DEPRECIATION AND AMORTIZATION
SDG&E	$	244	$	220	$	483	$	433
SoCalGas	188		180		375		353
Sempra Infrastructure	67		59		132		113
All other	2		4		4		6
Total	$	501	$	463	$	994	$	905
INTEREST INCOME
SDG&E	$	1	$	—	$	1	$	1
SoCalGas	1		—		1		—
Sempra Infrastructure	9		20		30		41
All other	4		1		8		1
Intercompany eliminations	—		(6)		—		(9)
Total	$	15	$	15	$	40	$	34
INTEREST EXPENSE
SDG&E	$	114	$	101	$	220	$	203
SoCalGas	45		40		85		79
Sempra Infrastructure	32		45		59		86
All other	81		79		151		162
Intercompany eliminations	(1)		(7)		(1)		(13)
Total	$	271	$	258	$	514	$	517
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	42	$	33	$	106	$	78
SoCalGas	19		8		103		102
Sempra Infrastructure	70		94		161		151
All other	(51)		4		44		(34)
Total	$	80	$	139	$	414	$	297
EQUITY EARNINGS (LOSSES)
Equity earnings, before income tax:
Sempra Texas Utilities	$	3	$	2	$	5	$	3
Sempra Infrastructure	156		133		297		267
All other	—		50		—		50
	159		185		302		320
Equity earnings (losses), net of income tax:
Sempra Texas Utilities	184		137		346		273
Sempra Infrastructure	32		(9)		53		38
	216		128		399		311
Total	$	375	$	313	$	701	$	631

(1)    Revenues for reportable segments include intersegment revenues of $3, $23, and $14 for the three months ended June 30, 2022; $7, $49, and $28 for the six months ended June 30, 2022; $2, $23, and $17 for the three months ended June 30, 2021 and $4, $48, and $26 for the six months ended June 30, 2021 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.

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SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176	$	186	$	410	$	398
SoCalGas	87		94		421		501
Sempra Texas Utilities	186		138		348		273
Sempra Infrastructure	183		53		278		255
All other	(73)		(47)		(286)		(129)
Total	$	559	$	424	$	1,171	$	1,298
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,090	$	1,072
SoCalGas					931		936
Sempra Infrastructure					336		415
All other					4		1
Total					$	2,361	$	2,424
					June 30, 2022		December 31, 2021
ASSETS
SDG&E					$	25,075	$	24,058
SoCalGas					21,354		20,324
Sempra Texas Utilities					13,406		13,047
Sempra Infrastructure					14,958		14,408
All other					1,984		1,399
Intersegment receivables					(1,195)		(1,191)
Total					$	75,582	$	72,045
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	13,406	$	13,047
Sempra Infrastructure					1,687		1,425
Total					$	15,093	$	14,472

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This combined MD&A for Sempra, SDG&E and SoCalGas should be read in conjunction with the Condensed Consolidated Financial Statements and the Notes thereto in this report, and the Consolidated Financial Statements and the Notes thereto, “Part I – Item 1A. Risk Factors” and “Part II – Item 7. MD&A” in the Annual Report.

OVERVIEW

Sempra is a California-based holding company with energy infrastructure investments in North America. Our businesses invest in, develop and operate energy infrastructure, and provide electric and gas services to customers through regulated public utilities. In the fourth quarter of 2021, we formed Sempra Infrastructure, which resulted in a change to our reportable segments. Historical segment disclosures have been restated to conform with the current presentation of our four reportable segments, which we discuss in Note 12 of the Notes to Condensed Consolidated Financial Statements in this report and in “Part I – Item 1. Business” in the Annual Report.

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RESULTS OF OPERATIONS

We discuss the following in Results of Operations:

▪Overall results of operations of Sempra;

▪Segment results;

▪Significant changes in revenues, costs and earnings; and

▪Impact of foreign currency and inflation rates on results of operations.

OVERALL RESULTS OF OPERATIONS OF SEMPRA

Sempra’s overall results of operations for the three months ended (Q2) and six months ended (YTD) June 30, 2022 and 2021 were as follows:

OVERALL RESULTS OF OPERATIONS OF SEMPRA

(Dollars and shares in millions, except per share amounts)

Our earnings and diluted EPS were impacted by variances discussed below in “Segment Results.”

SEGMENT RESULTS

This section presents earnings (losses) by Sempra segment, as well as Parent and other, and a related discussion of the changes in segment earnings (losses). Throughout the MD&A, our reference to earnings represents earnings attributable to common shares. Variance amounts presented are the after-tax earnings impact (based on applicable statutory tax rates), unless otherwise noted, and before NCI, where applicable.

SEMPRA EARNINGS (LOSSES) BY SEGMENT
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
SDG&E	$	176	$	186	$	410	$	398
SoCalGas	87		94		421		501
Sempra Texas Utilities	186		138		348		273
Sempra Infrastructure	183		53		278		255
Parent and other(1)	(73)		(47)		(286)		(129)
Earnings attributable to common shares	$	559	$	424	$	1,171	$	1,298

(1)    Includes intercompany eliminations recorded in consolidation and certain corporate costs.

SDG&E

The decrease in earnings of $10 million (5%) in the three months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$12 million higher income tax expense primarily from flow-through items and lower associated regulatory revenues; and

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▪$9 million higher interest expense; offset by

▪$6 million higher CPUC base operating margin, net of operating expenses; and

▪$5 million higher electric transmission margin.

The increase in earnings of $12 million (3%) in the six months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$30 million higher CPUC base operating margin, net of operating expenses; and

▪$8 million higher electric transmission margin; offset by

▪$13 million higher interest expense; and

▪$9 million higher income tax expense primarily from flow-through items and lower associated regulatory revenues.

SoCalGas

The decrease in earnings of $7 million (7%) in the three months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$32 million charge relating to civil litigation pertaining to the Leak; and

▪$4 million lower income tax benefits primarily from flow-through items; offset by

▪$30 million higher CPUC base operating margin, net of operating expenses.

The decrease in earnings of $80 million (16%) in the six months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$98 million charge relating to civil litigation pertaining to the Leak; and

▪$10 million in penalties related to the energy efficiency and advocacy OSCs, which we discuss in Note 4 of the Notes to Condensed Consolidated Financial Statements; offset by

▪$32 million higher CPUC base operating margin, net of operating expenses.

Sempra Texas Utilities

The increase in earnings of $48 million (35%) in the three months ended June 30, 2022 compared to the same period in 2021 was primarily due to higher equity earnings from Oncor Holdings driven by increased revenues from higher customer consumption primarily attributable to weather, rate updates to reflect increases in invested capital and customer growth, offset by increased expenses and operating costs attributable to invested capital.

The increase in earnings of $75 million (27%) in the six months ended June 30, 2022 compared to the same period in 2021 was primarily due to higher equity earnings from Oncor Holdings driven by increased revenues from rate updates to reflect increases in invested capital, higher customer consumption primarily attributable to weather and customer growth, offset by increased expenses and operating costs attributable to invested capital.

Sempra Infrastructure

The increase in earnings of $130 million in the three months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$78 million higher earnings from asset and supply optimization primarily driven by changes in natural gas prices offset by lower volumes;

▪$69 million favorable impact from foreign currency and inflation effects on our monetary positions in Mexico, net of foreign currency derivative effects, comprised of a $16 million unfavorable impact in 2022 compared to an $85 million unfavorable impact in 2021;

▪$16 million higher equity earnings from Cameron LNG JV primarily from higher maintenance revenues;

▪$13 million favorable U.S. tax impact in 2022 from converting SI Partners from a corporation to a partnership in October 2021;

▪$11 million higher transportation revenues primarily driven by higher rates;

▪$8 million higher earnings from the renewables business primarily due to the second phase of ESJ being placed in service in January 2022 and higher transmission rates; and

▪$7 million primarily due to the start of commercial operations of the Mexico City terminal in July 2021; offset by

▪$88 million earnings attributable to NCI in 2022 compared to $11 million earnings in 2021, primarily due to the sale of a 20% NCI in SI Partners to KKR in October 2021 and the sale of a 10% NCI in SI Partners to ADIA in June 2022, offset by the increase in our ownership interest in IEnova; and

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▪$8 million lower net income tax benefit primarily from the remeasurement of certain deferred income taxes and outside basis differences in JV investments.

The increase in earnings of $23 million (9%) in the six months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$43 million higher net income tax benefit primarily from the remeasurement of certain deferred income taxes and outside basis differences in JV investments;

▪$24 million higher transportation revenues primarily driven by higher rates;

▪$20 million primarily due to the start of commercial operations of the Veracruz and Mexico City terminals in March and July of 2021, respectively;

▪$18 million favorable U.S. tax impact in 2022 from converting SI Partners from a corporation to a partnership in October 2021;

▪$18 million higher equity earnings from Cameron LNG JV primarily from higher maintenance revenues; and

▪$12 million higher earnings from the renewables business primarily due to Border Solar and the second phase of ESJ being placed in service in March 2021 and January 2022, respectively; offset by

▪$122 million earnings attributable to NCI in 2022 compared to $44 million earnings in 2021, primarily due to the sale of a 20% NCI in SI Partners to KKR in October 2021 and the sale of a 10% NCI in SI Partners to ADIA in June 2022, offset by the increase in our ownership interest in IEnova;

▪$38 million unfavorable impact from foreign currency and inflation effects on our monetary positions in Mexico, net of foreign currency derivative effects, comprised of a $111 million unfavorable impact in 2022 compared to a $73 million unfavorable impact in 2021; and

▪$6 million lower earnings from asset and supply optimization primarily driven by changes in natural gas prices and lower volumes.

Parent and Other

The increase in losses of $26 million in the three months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$50 million equity earnings in 2021 related to our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs; and

▪$20 million net investment losses in 2022 compared to $15 million net investment gains in 2021 on dedicated assets in support of our employee nonqualified benefit plan and deferred compensation obligations; offset by

▪$30 million income tax benefit in 2022 from changes to a valuation allowance against certain tax credit carryforwards;

▪$19 million lower income tax expense from the interim period application of an annual forecasted consolidated ETR; and

▪$9 million lower preferred dividends due to the mandatory conversion of all series B preferred stock in July 2021.

The increase in losses of $157 million in the six months ended June 30, 2022 compared to the same period in 2021 was primarily due to:

▪$120 million deferred income tax expense associated with the change in our indefinite reinvestment assertion related to our foreign subsidiaries, which we discuss in Note 1 of the Notes to Condensed Consolidated Financial Statements;

▪$37 million net investment losses in 2022 compared to $17 million net investment gains in 2021 on dedicated assets in support of our employee nonqualified benefit plan and deferred compensation obligations; and

▪$50 million equity earnings in 2021 related to our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs; offset by

▪$30 million income tax benefit in 2022 from changes to a valuation allowance against certain tax credit carryforwards;

▪$19 million lower preferred dividends due to the mandatory conversion of all series B preferred stock in July 2021;

▪$5 million income tax benefit in 2022 compared to an $8 million income tax expense in 2021 from the interim period application of an annual forecasted consolidated ETR; and

▪$11 million lower net interest expense.

SIGNIFICANT CHANGES IN REVENUES, COSTS AND EARNINGS

This section contains a discussion of the differences between periods in the specific line items of the Condensed Consolidated Statements of Operations for Sempra, SDG&E and SoCalGas.

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Utilities Revenues and Cost of Sales

Our utilities revenues include natural gas revenues at SoCalGas and SDG&E and Sempra Infrastructure’s Ecogas and electric revenues at SDG&E. Intercompany revenues included in the separate revenues of each utility are eliminated in Sempra’s Condensed Consolidated Statements of Operations.

SoCalGas and SDG&E operate under a regulatory framework that permits:

▪The cost of natural gas purchased for core customers (primarily residential and small commercial and industrial customers) to be passed through to customers in rates substantially as incurred. SoCalGas’ Gas Cost Incentive Mechanism provides SoCalGas the opportunity to share in the savings and/or costs from buying natural gas for its core customers at prices below or above monthly market-based benchmarks. This mechanism permits full recovery of costs incurred when average purchase costs are within a price range around the benchmark price. Any higher costs incurred or savings realized outside this range are shared between the core customers and SoCalGas. We provide further discussion in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report.

▪SDG&E to recover the actual cost incurred to generate or procure electricity based on annual estimates of the cost of electricity supplied to customers. The differences in cost between estimates and actual are recovered or refunded in subsequent periods through rates.

▪SoCalGas and SDG&E to recover certain program expenditures and other costs authorized by the CPUC, or “refundable programs.”

Because changes in SoCalGas’ and SDG&E’s cost of natural gas and/or electricity are recovered in rates, changes in these costs are offset in the changes in revenues and therefore do not impact earnings. In addition to the changes in cost or market prices, natural gas or electric revenues recorded during a period are impacted by the difference between customer billings and recorded or CPUC-authorized amounts. These differences are required to be balanced over time, resulting in over- and undercollected regulatory balancing accounts. We discuss balancing accounts and their effects further in Note 4 of the Notes to Condensed Consolidated Financial Statements in this report and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.

SoCalGas’ and SDG&E’s revenues are decoupled from, or not tied to, actual sales volumes. SoCalGas recognizes annual authorized revenue for core natural gas customers using seasonal factors established in the Triennial Cost Allocation Proceeding, resulting in a significant portion of SoCalGas’ earnings being recognized in the first and fourth quarters of each year. SDG&E’s authorized revenue recognition is also impacted by seasonal factors, resulting in higher earnings in the third quarter when electric loads are typically higher than in the other three quarters of the year. We discuss this decoupling mechanism and its effects further in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report.

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The table below summarizes utilities revenues and cost of sales.

UTILITIES REVENUES AND COST OF SALES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Natural gas revenues:
SoCalGas	$	1,501	$	1,124	$	3,494	$	2,632
SDG&E	207		160		532		428
Sempra Infrastructure	20		17		48		44
Eliminations and adjustments	(24)		(23)		(50)		(49)
Total	1,704		1,278		4,024		3,055
Electric revenues:
SDG&E	1,192		1,158		2,312		2,227
Eliminations and adjustments	(3)		(2)		(6)		(3)
Total	1,189		1,156		2,306		2,224
Total utilities revenues	$	2,893	$	2,434	$	6,330	$	5,279
Cost of natural gas(1):
SoCalGas	$	459	$	223	$	1,136	$	496
SDG&E	69		40		195		122
Sempra Infrastructure	5		6		14		12
Eliminations and adjustments	(5)		(8)		(15)		(20)
Total	528		261		1,330		610
Cost of electric fuel and purchased power(1):
SDG&E	269		304		490		545
Eliminations and adjustments	(18)		(20)		(34)		(29)
Total	251		284		456		516
Total utilities cost of sales	$	779	$	545	$	1,786	$	1,126

(1)     Excludes depreciation and amortization, which are presented separately on the Sempra, SDG&E and SoCalGas Condensed Consolidated Statements of Operations.

Natural Gas Revenues and Cost of Natural Gas

The table below summarizes the average cost of natural gas sold by Sempra California and included in cost of natural gas. The average cost of natural gas sold at each utility is impacted by market prices, as well as transportation, tariff and other charges.

SEMPRA CALIFORNIA AVERAGE COST OF NATURAL GAS
(Dollars per thousand cubic feet)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
SoCalGas	$	7.63	$	3.73	$	7.11	$	3.01
SDG&E	7.84		4.42		7.16		4.44

In the three months ended June 30, 2022, our natural gas revenues increased by $426 million (33%) to $1.7 billion compared to the same period in 2021 primarily due to:

▪$377 million increase at SoCalGas, which included:

◦$236 million increase in cost of natural gas sold, which we discuss below,

◦$65 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M,

◦$52 million higher CPUC-authorized revenues, and

◦$12 million higher revenues from incremental and balanced capital projects; and

▪$47 million increase at SDG&E, which included:

◦$29 million increase in cost of natural gas sold, which we discuss below, and

◦$13 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M.

In the three months ended June 30, 2022, our cost of natural gas increased by $267 million to $528 million compared to the same period in 2021 primarily due to:

▪$236 million increase at SoCalGas primarily due to higher average natural gas prices; and

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▪$29 million increase at SDG&E primarily due to higher average natural gas prices.

In the six months ended June 30, 2022, our natural gas revenues increased by $969 million (32%) to $4.0 billion compared to the same period in 2021 primarily due to:

▪$862 million increase at SoCalGas, which included:

◦$640 million increase in cost of natural gas sold, which we discuss below,

◦$82 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M,

◦$81 million higher CPUC-authorized revenues,

◦$33 million higher revenues from incremental and balanced capital projects, and

◦$24 million higher revenues associated with impacts resulting from changes in tax laws tracked in the income tax expense memorandum account; and

▪$104 million increase at SDG&E, which included:

◦$73 million increase in cost of natural gas sold, which we discuss below,

◦$13 million higher revenues from balanced capital projects,

◦$12 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M, and

◦$6 million higher CPUC-authorized revenues.

In the six months ended June 30, 2022, our cost of natural gas increased by $720 million to $1.3 billion compared to the same period in 2021 primarily due to:

▪$640 million increase at SoCalGas primarily due to higher average natural gas prices; and

▪$73 million increase at SDG&E primarily due to higher average natural gas prices.

Electric Revenues and Cost of Electric Fuel and Purchased Power

In the three months ended June 30, 2022, our electric revenues, substantially all of which are at SDG&E, increased by $33 million (3%) remaining at $1.2 billion compared to the same period in 2021 primarily due to:

▪$35 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M;

▪$17 million higher CPUC-authorized revenues;

▪$16 million higher revenues associated with SDG&E’s wildfire mitigation plan;

▪$12 million higher revenues from transmission operations; and

▪$8 million higher revenues associated with lower income tax benefits from flow-through items; offset by

▪$35 million lower cost of electric fuel and purchased power, which we discuss below; and

▪$10 million lower revenues associated with impacts resulting from changes in tax laws tracked in the income tax expense memorandum account.

Our utility cost of electric fuel and purchased power includes utility-owned generation, power purchased from third parties, and net power purchases and sales to the California ISO. In the three months ended June 30, 2022, the cost of electric fuel and purchased power decreased by $33 million (12%) to $251 million compared to the same period in 2021 primarily due to $35 million at SDG&E from higher sales to the California ISO due to higher market prices and lower customer demand primarily due to departing load now served by CCAs, offset by higher utility-owned generation costs.

In the six months ended June 30, 2022, our electric revenues, substantially all of which are at SDG&E, increased by $82 million (4%) to $2.3 billion compared to the same period in 2021 primarily due to:

▪$37 million higher recovery of costs associated with refundable programs, which revenues are offset in O&M;

▪$34 million higher CPUC-authorized revenues;

▪$32 million higher revenues associated with SDG&E’s wildfire mitigation plan;

▪$22 million higher revenues from transmission operations; and

▪$14 million higher revenues associated with lower income tax benefits from flow-through items; offset by

▪$55 million lower cost of electric fuel and purchased power, which we discuss below.

In the six months ended June 30, 2022, the cost of electric fuel and purchased power decreased by $60 million (12%) to $456 million compared to the same period in 2021 primarily due to:

▪$55 million at SDG&E from higher sales to the California ISO due to higher market prices and lower customer demand primarily due to departing load now served by CCAs, offset by higher utility-owned generation costs; and

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▪$5 million higher intercompany eliminations associated with sales between SDG&E and Sempra Infrastructure due to the acquisition of ESJ in March 2021.

Energy-Related Businesses: Revenues and Cost of Sales

The table below shows revenues and cost of sales for our energy-related businesses.

ENERGY-RELATED BUSINESSES: REVENUES AND COST OF SALES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Revenues:
Sempra Infrastructure	$	669	$	324	$	1,065	$	746
Parent and other(1)	(15)		(17)		(28)		(25)
Total revenues	$	654	$	307	$	1,037	$	721
Cost of sales(2):
Sempra Infrastructure	$	289	$	119	$	424	$	227
Parent and other(1)	—		—		—		1
Total cost of sales	$	289	$	119	$	424	$	228

(1)    Includes eliminations of intercompany activity.

(2)    Excludes depreciation and amortization, which are presented separately on Sempra’s Condensed Consolidated Statements of Operations.

In the three months ended June 30, 2022, revenues from our energy-related businesses increased by $347 million to $654 million compared to the same period in 2021 primarily due to:

▪$266 million increase in revenues from asset and supply optimization from contracts to sell natural gas and LNG to third parties, including:

◦$230 million from higher natural gas prices and lower unrealized losses on commodity derivatives offset by lower volumes, and

◦$36 million primarily from higher diversion fees due to higher natural gas prices;

▪$24 million higher revenues from TdM mainly due to higher power prices offset by lower volumes;

▪$20 million higher revenues from the renewables business primarily due to higher transmission rates and the second phase of ESJ being placed in service in January 2022;

▪$14 million higher transportation revenues primarily driven by higher rates; and

▪$11 million higher revenues primarily from the Mexico City terminal placed in service in July 2021.

In the three months ended June 30, 2022, the cost of sales for our energy-related businesses increased by $170 million to $289 million compared to the same period in 2021 primarily due to higher natural gas prices and higher LNG purchases related to asset and supply optimization and higher natural gas prices offset by lower volumes at TdM.

In the six months ended June 30, 2022, revenues from our energy-related businesses increased by $316 million (44%) to $1.0 billion compared to the same period in 2021 primarily due to:

▪$197 million increase in revenues from asset and supply optimization from contracts to sell natural gas and LNG to third parties, including:

◦$157 million from higher natural gas prices and lower unrealized losses on commodity derivatives offset by lower volumes, and

◦$40 million primarily from higher diversion fees due to higher natural gas prices;

▪$36 million higher revenues from the renewables business primarily due to Border Solar and the second phase of ESJ being placed in service in March 2021 and January 2022, respectively, and the acquisition of ESJ in March 2021;

▪$35 million higher transportation revenues primarily driven by higher rates;

▪$28 million higher revenues primarily from the Veracruz and Mexico City terminals placed in service in March and July of 2021, respectively; and

▪$14 million higher revenues from TdM mainly due to higher power prices, offset by lower volumes from scheduled major maintenance completed in March 2022, which resulted in increased plant reliability.

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In the six months ended June 30, 2022, the cost of sales for our energy-related businesses increased by $196 million to $424 million compared to the same period in 2021 primarily due to higher natural gas prices and higher LNG purchases related to asset and supply optimization and higher natural gas prices offset by lower volumes from scheduled major maintenance completed in March 2022 at TdM.

Operation and Maintenance

In the three months ended June 30, 2022, O&M increased by $138 million (13%) to $1.2 billion compared to the same period in 2021 primarily due to:

▪$80 million increase at SoCalGas primarily due to:

◦$65 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$15 million higher non-refundable operating costs;

▪$47 million increase at SDG&E primarily due to higher expenses associated with refundable programs, which costs incurred are recovered in revenue; and

▪$24 million increase at Sempra Infrastructure primarily due to:

◦$13 million from the renewables business primarily due to construction repairs and maintenance at Ventika, and

◦$6 million primarily due to the start of commercial operations of the Mexico City terminal in July 2021; offset by

▪$13 million decrease at Parent and other primarily from lower deferred compensation expense.

In the six months ended June 30, 2022, O&M increased by $223 million (11%) to $2.2 billion compared to the same period in 2021 primarily due to:

▪$128 million increase at SoCalGas primarily due to:

◦$82 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$46 million higher non-refundable operating costs;

▪$54 million increase at SDG&E primarily due to:

◦$49 million higher expenses associated with refundable programs, which costs incurred are recovered in revenue, and

◦$5 million higher non-refundable operating costs; and

▪$52 million increase at Sempra Infrastructure primarily due to:

◦$20 million from the renewables business primarily due to construction repairs and maintenance at Ventika,

◦$17 million primarily due to the start of commercial operations of the Veracruz and Mexico City terminals in March and July of 2021, respectively, and

◦$14 million higher operating costs at TdM primarily from higher purchased materials and services due to scheduled major maintenance completed in March 2022; offset by

▪$11 million decrease at Parent and other primarily from lower deferred compensation expense.

Aliso Canyon Litigation and Regulatory Matters

In the three months and six months ended June 30, 2022, SoCalGas recorded charges of $45 million and $137 million, respectively, relating to civil litigation pertaining to the Leak. We describe these charges in Note 11 of the Notes to Condensed Consolidated Financial Statements.

Other (Expense) Income, Net

As part of our central risk management function, we may enter into foreign currency derivatives to hedge SI Partners’ exposure to movements in the Mexican peso from its controlling interest in IEnova. The gains/losses associated with these derivatives are included in Other Income, Net, as described below, and partially mitigate the transactional effects of foreign currency and inflation included in Income Tax Expense for SI Partners’ consolidated entities and in Equity Earnings for SI Partners’ equity method investments. We discuss policies governing our risk management in “Part II – Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in the Annual Report.

Other expense, net, in the three months ended June 30, 2022 was $1 million compared to other income, net, of $72 million in the same period in 2021 primarily due to:

▪$34 million investment losses in 2022 compared to $19 million investment gains in 2021 on dedicated assets in support of our executive retirement and deferred compensation plans; and

▪$4 million losses in 2022 from impacts associated with interest rate and foreign exchange instruments and foreign currency transactions compared to $33 million gains in 2021 primarily due to:

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◦$28 million in foreign currency gains in 2021 on a Mexican peso-denominated loan to IMG, which is offset in Equity Earnings, and

◦$7 million gains in 2021 on cross-currency swaps as a result of fluctuation of the Mexican peso; offset by

▪$6 million lower non-service component of net periodic benefit cost.

In the six months ended June 30, 2022, other income, net, decreased by $70 million to $37 million compared to the same period in 2021 primarily due to:

▪$47 million investment losses in 2022 compared to $28 million investment gains in 2021 on dedicated assets in support of our executive retirement and deferred compensation plans;

▪$10 million in penalties at SoCalGas related to the energy efficiency and advocacy OSCs; and

▪$1 million higher net losses from impacts associated with interest rate and foreign exchange instruments and foreign currency transactions primarily due to:

◦$11 million foreign currency losses in 2022 compared to $5 million foreign currency gains in 2021 on a Mexican peso-denominated loan to IMG, which is offset in Equity Earnings, and

◦$11 million losses in 2022 compared to $2 million gains in 2021 on other foreign currency transactional effects, offset by

◦$6 million gains in 2022 on cross-currency swaps compared to $23 million losses in 2021 on foreign currency derivatives and cross-currency swaps as a result of fluctuation of the Mexican peso; offset by

▪$18 million higher non-service component of net periodic benefit credit.

Income Taxes

The table below shows the income tax expense and ETRs for Sempra, SDG&E and SoCalGas.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2022			2021			2022			2021
Sempra:
Income tax expense	$	80		$	139		$	414		$	297
Income before income taxes and equity earnings	$	364		$	281		$	1,029		$	1,049
Equity earnings, before income tax(1)	159			185			302			320
Pretax income	$	523		$	466		$	1,331		$	1,369
Effective income tax rate	15		%	30		%	31		%	22		%
SDG&E:
Income tax expense	$	42		$	33		$	106		$	78
Income before income taxes	$	218		$	219		$	516		$	476
Effective income tax rate	19		%	15		%	21		%	16		%
SoCalGas:
Income tax expense	$	19		$	8		$	103		$	102
Income before income taxes	$	107		$	103		$	525		$	604
Effective income tax rate	18		%	8		%	20		%	17		%

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

Sempra

In the three months ended June 30, 2022, Sempra’s income tax expense decreased by $59 million (42%) compared to the same period in 2021 primarily due to:

▪$14 million income tax expense in 2022 compared to $83 million income tax expense in 2021 from foreign currency and inflation effects on our monetary positions in Mexico and associated derivatives;

▪$30 million income tax benefit in 2022 from changes to a valuation allowance against certain tax credit carryforwards; and

▪$13 million favorable U.S. tax impact in 2022 from converting SI Partners from a corporation to a partnership in October 2021; offset by

▪$16 million income tax benefit in 2021 from the remeasurement of certain deferred income taxes;

▪lower income tax benefit from flow-through items; and

▪higher pretax income.

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In the six months ended June 30, 2022, Sempra’s income tax expense increased by $117 million (39%) compared to the same period in 2021 primarily due to:

▪$120 million deferred income tax expense associated with the change in our indefinite reinvestment assertion related to our foreign subsidiaries, which we discuss in Note 1 to Condensed Consolidated Financial Statements;

▪$84 million income tax expense in 2022 compared to $41 million income tax expense in 2021 from foreign currency and inflation effects on our monetary positions in Mexico and associated derivatives; and

▪lower income tax benefit from flow-through items; offset by

▪$30 million income tax benefit in 2022 from changes to a valuation allowance against certain tax credit carryforwards;

▪$18 million higher net income tax benefit in 2022 from the remeasurement of certain deferred income taxes; and

▪$18 million favorable U.S. income tax impact in 2022 from converting SI Partners from a corporation to a partnership in October 2021.

We discuss the impact of foreign currency exchange rates and inflation on income taxes below in “Impact of Foreign Currency and Inflation Rates on Results of Operations.” See Note 1 of the Notes to Condensed Consolidated Financial Statements in this report and Notes 1 and 8 of the Notes to Consolidated Financial Statements in the Annual Report for further details about our accounting for income taxes and items subject to flow-through treatment.

SDG&E

In the three months ended June 30, 2022, SDG&E’s income tax expense increased by $9 million (27%) compared to the same period in 2021 primarily due to lower income tax benefits from flow-through items.

In the six months ended June 30, 2022, SDG&E’s income tax expense increased by $28 million (36%) compared to the same period in 2021 primarily due to higher pretax income and lower income tax benefits from flow-through items.

SoCalGas

In the three months ended June 30, 2022, SoCalGas’ income tax expense increased by $11 million compared to the same period in 2021 primarily due to lower income tax benefits from flow-through items.

In the six months ended June 30, 2022, SoCalGas’ income tax expense increased by $1 million (1%) compared to the same period in 2021 primarily due to lower income tax benefits from flow-through items partially offset by lower pretax income.

Equity Earnings

In the three months ended June 30, 2022, equity earnings increased by $62 million (20%) to $375 million compared to the same period in 2021 primarily due to:

▪$47 million higher equity earnings at Oncor Holdings primarily due to increased revenues from higher customer consumption primarily attributable to weather, rate updates to reflect increases in invested capital and customer growth, offset by increased expenses and operating costs attributable to invested capital;

▪$23 million higher equity earnings at Cameron LNG JV primarily due to higher maintenance revenues; and

▪$35 million higher equity earnings at IMG, primarily due to foreign currency effects, including $28 million foreign currency losses in 2021 on IMG’s Mexican peso-denominated loans from its JV owners, which is fully offset in Other (Expense) Income, Net, and lower interest expense; offset by

▪$50 million equity earnings in 2021 related our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs.

In the six months ended June 30, 2022, equity earnings increased by $70 million (11%) to $701 million compared to the same period in 2021 primarily due to:

▪$73 million higher equity earnings at Oncor Holdings primarily due to increased revenues from rate updates to reflect increases in invested capital, higher customer consumption primarily attributable to weather and customer growth, offset by increased expenses and operating costs attributable to invested capital;

▪$30 million higher equity earnings at Cameron LNG JV primarily due to higher maintenance revenues; and

▪$14 million higher equity earnings at IMG, primarily due to foreign currency effects, including $11 million foreign currency gains in 2022 compared to $5 million foreign currency losses in 2021 on IMG’s Mexican peso-denominated loans from its JV owners, which is fully offset in Other (Expense) Income, Net, and lower interest expense offset by higher income tax expense; offset by

▪$50 million equity earnings in 2021 related to our investment in RBS Sempra Commodities to settle pending VAT matters and related legal costs.

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Earnings Attributable to Noncontrolling Interests

In the three months ended June 30, 2022, earnings attributable to NCI increased by $78 million to $88 million compared to the same period in 2021 primarily due to:

▪$40 million increase as a result of a decrease in our ownership interest in SI Partners net of an increase in our ownership interest in IEnova; and

▪$37 million primarily due to an increase in SI Partners subsidiaries net income.

In the six months ended June 30, 2022, earnings attributable to NCI increased by $79 million to $122 million compared to the same period in 2021 primarily due to:

▪$57 million increase as a result of a decrease in our ownership interest in SI Partners net of an increase in our ownership interest in IEnova; and

▪$21 million primarily due to an increase in SI Partners subsidiaries net income.

Preferred Dividends

In the three months and six months ended June 30, 2022, preferred dividends decreased by $9 million to $11 million and $19 million to $22 million, respectively, compared to the same period in 2021 primarily due to the conversion of all series B preferred stock in July 2021.

IMPACT OF FOREIGN CURRENCY AND INFLATION RATES ON RESULTS OF OPERATIONS

Because our natural gas distribution utility in Mexico, Ecogas, uses its local currency as its functional currency, revenues and expenses are translated into U.S. dollars at average exchange rates for the period for consolidation in Sempra’s results of operations. We discuss further the impact of foreign currency and inflation rates on results of operations, including impacts on income taxes and related hedging activity, in “Part II – Item 7. MD&A – Impact of Foreign Currency and Inflation Rates on Results of Operations” in the Annual Report.

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Foreign Currency Translation

Any difference in average exchange rates used for the translation of income statement activity from year to year can cause a variance in Sempra’s comparative results of operations. In the three months and six months ended June 30, 2022, the change in our earnings as a result of foreign currency translation rates was negligible compared to the same period in 2021.

Transactional Impacts

Income statement activities at our Mexico operations and their JVs are also impacted by transactional gains and losses, a summary of which is shown in the table below:

TRANSACTIONAL (LOSSES) GAINS FROM FOREIGN CURRENCY AND INFLATION EFFECTS AND ASSOCIATED DERIVATIVES
(Dollars in millions)
	Total reported amounts				Transactional (losses) gains included in reported amounts
	Three months ended June 30,
	2022		2021		2022		2021
Other (expense) income, net	$	(1)	$	72	$	(4)	$	33
Income tax expense	(80)		(139)		(14)		(83)
Equity earnings	375		313		—		(35)
Net income	659		455		(18)		(85)
Earnings attributable to noncontrolling interests	(88)		(10)		2		13
Earnings attributable to common shares	559		424		(16)		(72)
	Six months ended June 30,
	2022		2021		2022		2021
Other (expense) income, net	$	37	$	107	$	(17)	$	(16)
Income tax expense	(414)		(297)		(84)		(41)
Equity earnings	701		631		(12)		(16)
Net income	1,316		1,383		(113)		(73)
Earnings attributable to noncontrolling interests	(122)		(43)		22		4
Earnings attributable to common shares	1,171		1,298		(91)		(69)

CAPITAL RESOURCES AND LIQUIDITY

OVERVIEW

Sempra

Impact of the COVID-19 Pandemic

Our businesses that invest in, develop and operate energy infrastructure and provide electric and gas services to customers have been identified as critical or essential services in the U.S. and Mexico and have continued to operate throughout the COVID-19 pandemic. As our businesses continue to operate, our priority is the safety of our employees, customers, partners and the communities we serve. We and other companies, including our partners, are taking steps to try to protect the health and well-being of our employees and other stakeholders. We continue to work closely with local, state and federal authorities in an effort to provide essential services with minimum interruption to customers and in accordance with applicable orders, including potential vaccination mandates.

For a further discussion of risks and uncertainties related to the COVID-19 pandemic, see “Part I – Item 1A. Risk Factors” in the Annual Report.

Liquidity

We expect to meet our cash requirements through cash flows from operations, unrestricted cash and cash equivalents, borrowings under or supported by our credit facilities, other incurrences of debt including issuing debt securities and obtaining term loans, distributions from our equity method investments, project financing and funding from minority interest owners. We believe that

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these cash flow sources, combined with available funds, will be adequate to fund our operations in both the short-term and long-term, including to:

▪finance capital expenditures

▪repay debt

▪fund dividends

▪meet liquidity requirements

▪fund capital contribution requirements

▪fund expenditures related to the natural gas leak at SoCalGas’ Aliso Canyon natural gas storage facility

▪repurchase shares of our common stock

▪fund new business or asset acquisitions or start-ups

Sempra, SDG&E and SoCalGas currently have reasonable access to the money markets and capital markets and are not currently constrained in their ability to borrow money at market rates from commercial banks, under existing revolving credit facilities, through public offerings registered with the SEC, or through private placements of debt supported by our revolving credit facilities in the case of commercial paper. However, our ability to access the money markets and capital markets or obtain credit from commercial banks outside of our committed revolving credit facilities could become materially constrained if changing economic conditions or disruptions to or volatility in the money markets and capital markets worsen. These sources of funding also may become less attractive to the extent interest rates rise. In addition, our financing activities and actions by credit rating agencies, as well as many other factors, could negatively affect the availability and cost of both short-term and long-term financing. Also, cash flows from operations may be impacted by the timing of commencement and completion, and potentially cost overruns, of large projects and other material events, such as significant outflows resulting from the agreements expected to resolve certain material litigation related to the Leak. If cash flows from operations were to be significantly reduced or we were unable to borrow under acceptable terms, we would likely first reduce or postpone discretionary capital expenditures (not related to safety) and investments in new businesses. We monitor our ability to finance the needs of our operating, investing and financing activities in a manner consistent with our goal to maintain our investment-grade credit ratings.

Available Funds

Our committed lines of credit provide liquidity and support commercial paper. Sempra, SDG&E and SoCalGas each have five-year credit agreements expiring in 2024, SI Partners has a three-year credit agreement expiring in 2024 and IEnova has committed lines of credit that expire in 2023 and 2024. In addition, IEnova and ECA LNG Phase 1 have uncommitted revolving credit facilities that expire in 2022 and 2023.

AVAILABLE FUNDS AT JUNE 30, 2022
(Dollars in millions)
	Sempra		SDG&E		SoCalGas
Unrestricted cash and cash equivalents(1)	$	1,931	$	533	$	416
Available unused credit(2)	9,150		1,500		750

(1)    Amounts at Sempra include $92 held in non-U.S. jurisdictions. We discuss repatriation in Note 1 of the Notes to Condensed Consolidated Financial Statements in this report and Note 8 of the Notes to Consolidated Financial Statements in the Annual Report.

(2)    Available unused credit is the total available on committed and uncommitted lines of credit that we discuss in Note 7 of the Notes to Condensed Consolidated Financial Statements. Because our commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit.

Short-Term Borrowings

We use short-term debt primarily to meet liquidity requirements, fund shareholder dividends, and temporarily finance capital expenditures, acquisitions or start-ups. SDG&E and SoCalGas use short-term debt primarily to meet working capital needs or to help fund event-specific costs, such as upcoming payments at SoCalGas related to resolving certain civil litigation pertaining to the Leak. Commercial paper and lines of credit were our primary sources of short-term debt funding in the first six months of 2022.

We discuss our short-term debt activities in Note 7 of the Notes to Condensed Consolidated Financial Statements and below in “Sources and Uses of Cash.”

Long-Term Debt Activities

Significant issuances of and payments on long-term debt in the first six months of 2022 included the following:

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LONG-TERM DEBT ISSUANCES AND PAYMENTS
(Dollars in millions)
Issuances:	Amount at issuance		Maturity
Sempra 3.30% fixed rate notes	$	750	2025
Sempra 3.70% fixed rate notes	500		2029
SDG&E variable rate term loan	400		2024
SDG&E 3.00% first mortgage bonds	500		2032
SDG&E 3.70% first mortgage bonds	500		2052
SoCalGas 2.95% fixed rate notes	700		2027
Sempra Infrastructure variable rate notes	114		2025
Sempra Infrastructure 3.25% fixed rate notes	400		2032
Payments:	Payments		Maturity
SDG&E 1.914% amortizing first mortgage bonds	17		2022
Sempra Infrastructure amortizing variable rate notes (5.13% after floating-to-fixed rate swaps)	23		2022

We discuss our long-term debt activities, including the use of proceeds on long-term debt issuances, in Note 7 of the Notes to Condensed Consolidated Financial Statements.

Credit Ratings

We provide additional information about the credit ratings of Sempra, SDG&E and SoCalGas in “Part I – Item 1A. Risk Factors” and “Part II – Item 2. MD&A – Capital Resources and Liquidity” in the Annual Report.

The credit ratings of Sempra, SDG&E and SoCalGas remained at investment grade levels in the first six months of 2022.

CREDIT RATINGS AT JUNE 30, 2022
	Sempra	SDG&E	SoCalGas
Moody’s	Baa2 with a stable outlook	A3 with a stable outlook	A2 with a stable outlook
S&P	BBB+ with a negative outlook	BBB+ with a stable outlook	A with a negative outlook
Fitch	BBB+ with a stable outlook	BBB+ with a stable outlook	A with a stable outlook

A downgrade of Sempra’s or any of its subsidiaries’ credit ratings or rating outlooks may, depending on the severity, result in the imposition of financial and/or other burdensome covenants and a requirement for collateral to be posted in the case of certain financing arrangements and may materially and adversely affect the market prices of their equity and debt securities, the rates at which borrowings are made and commercial paper is issued, and the various fees on their outstanding credit facilities. This could make it more costly for Sempra, SDG&E, SoCalGas and Sempra’s other subsidiaries to issue debt securities, to borrow under credit facilities and to raise certain other types of financing.

Sempra has agreed that, if the credit rating of Oncor’s senior secured debt by any of the three major rating agencies falls below BBB (or the equivalent), Oncor will suspend dividends and other distributions (except for contractual tax payments), unless otherwise allowed by the PUCT. Oncor’s senior secured debt was rated A2, A+ and A at Moody’s, S&P and Fitch, respectively, at June 30, 2022.

Loans with Affiliates

At June 30, 2022, Sempra had a $626 million loan due from an unconsolidated affiliate and $282 million in loans due to unconsolidated affiliates. In July 2022, the loan due from an unconsolidated affiliate was paid in full, prior to its March 2023 maturity date.

Sempra California

SDG&E’s and SoCalGas’ operations have historically provided relatively stable earnings and liquidity. Their future performance and liquidity will depend primarily on the ratemaking and regulatory process, environmental regulations, economic conditions, actions by the California legislature, litigation and the changing energy marketplace, as well as other matters described in this report. SDG&E and SoCalGas expect that the available unused credit from their credit facilities described above, which also supports their commercial paper programs, cash flows from operations, and other incurrences of debt including issuing debt securities and obtaining term loans will continue to be adequate to fund their respective current operations and planned capital expenditures. Additionally, as we discuss below, Sempra elected to make equity contributions to SoCalGas of $800 million in

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September 2021 and $150 million in June 2022 and expects to make an additional equity contribution of approximately $500 million in August 2022. These voluntary equity contributions are intended to assist SoCalGas in maintaining its approved capital structure. SDG&E and SoCalGas manage their capital structures and pay dividends when appropriate and as approved by their respective boards of directors.

As we discuss in Note 4 of the Notes to Condensed Consolidated Financial Statements in this report and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report, changes in balancing accounts for significant costs at SDG&E and SoCalGas, particularly a change between over- and undercollected status, may have a significant impact on cash flows. These changes generally represent the difference between when costs are incurred and when they are ultimately recovered or refunded in rates through billings to customers.

COVID-19 Pandemic Protections

SDG&E and SoCalGas are continuing to monitor the impacts of the COVID-19 pandemic on cash flows and results of operations. Some customers have experienced and continue to experience a diminished ability to pay their electric or gas bills, leading to slower payments and higher levels of nonpayment than has been the case historically. These impacts could become significant and could require modifications to our financing plans.

In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented a number of measures to assist customers, including automatically enrolling residential and small business customers with past-due balances in long-term repayment plans.

In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and applied the amounts directly to eligible customer accounts to reduce past due balances. In June 2022, AB 205 was approved establishing, among other things, the 2022 California Arrearage Payment Program. SDG&E and SoCalGas expect to apply for funding from this program on behalf of their residential customers with past due balances and, if approved, receive such funding in the first quarter of 2023.

SDG&E

Authorized Cost of Capital, Subject to the CCM

As we discuss in Note 4 of the Notes to Condensed Consolidated Financial Statements, in December 2019, the CPUC approved the cost of capital for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM.

For the measurement period that ended September 30, 2021, the CCM would trigger for SDG&E if the CPUC determines that the CCM should be implemented because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event such that the CCM should not apply. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects to receive a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022.

We further discuss the CCM in “Part I – Item 1A. Risk Factors” in the Annual Report.

Wildfire Fund

The carrying value of SDG&E’s Wildfire Fund asset totals $346 million at June 30, 2022. We describe the Wildfire Legislation and related accounting treatment and SDG&E’s commitment to make annual shareholder contributions to the Wildfire Fund through 2028 in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

SDG&E is exposed to the risk that the participating California electric IOUs may incur third-party wildfire costs for which they will seek recovery from the Wildfire Fund with respect to wildfires that have occurred since enactment of the Wildfire Legislation

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in July 2019. In such a situation, SDG&E may recognize a reduction of its Wildfire Fund asset and record an impairment charge against earnings when there is a reduction of the available coverage due to recoverable claims from any of the participating IOUs. PG&E has indicated that it will seek reimbursement from the Wildfire Fund for losses associated with the Dixie Fire, which burned from July 2021 through October 2021 and was reported to be the largest single wildfire (measured by acres burned) in California history. If any California electric IOU’s equipment is determined to be a cause of a fire, it could have a material adverse effect on SDG&E’s and Sempra’s financial condition and results of operations up to the carrying value of our Wildfire Fund asset, with additional potential material exposure if SDG&E’s equipment is determined to be a cause of a fire. In addition, the Wildfire Fund could be completely exhausted due to fires in the other California electric IOUs’ service territories, by fires in SDG&E’s service territory or by a combination thereof. In the event that the Wildfire Fund is materially diminished, exhausted or terminated, SDG&E will lose the protection afforded by the Wildfire Fund, and as a consequence, a fire in SDG&E’s service territory could have a material adverse effect on SDG&E’s and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Wildfire Cost Recovery Mechanism

In July 2021, SDG&E filed a request with the CPUC to establish an interim cost recovery mechanism that would recover in rates 50% of its wildfire mitigation plan costs. The proposed recovery would be incremental to wildfire costs currently authorized in its GRC and would be subject to reasonableness review. In May 2022, the CPUC issued a final decision denying SDG&E’s request and directing SDG&E to file for the review and recovery of its wildfire mitigation plan costs through its next GRC or a separate application. SDG&E proposes to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in mid-2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023.

Off-Balance Sheet Arrangements

SDG&E has entered into PPAs and tolling agreements that are variable interests in unconsolidated entities. We discuss variable interests in Note 1 of the Notes to Condensed Consolidated Financial Statements.

SoCalGas

SoCalGas’ future performance and liquidity will be impacted by the resolution of legal, regulatory and other matters concerning the Leak, which we discuss below and in Note 11 of the Notes to Condensed Consolidated Financial Statements in this report and in “Part I – Item 1A. Risk Factors” in the Annual Report.

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 located in Los Angeles County.

Cost Estimate, Accounting Impact and Insurance. At June 30, 2022, SoCalGas estimates certain costs related to the Leak are $3,361 million (the cost estimate). This cost estimate may increase significantly as more information becomes available. At June 30, 2022, $2,003 million of the cost estimate is accrued in Reserve for Aliso Canyon Costs and $4 million of the cost estimate is accrued in Deferred Credits and Other on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets.

Sempra elected to make equity contributions to SoCalGas of $800 million in September 2021 and $150 million in June 2022 and expects to make an additional equity contribution of approximately $500 million in August 2022. These voluntary equity contributions are intended to assist SoCalGas in maintaining its approved capital structure. SoCalGas expects to make a payment of approximately $1.8 billion on or around August 30, 2022 related to the settlement of the Individual Plaintiff Litigation. SoCalGas plans to fund the settlement payment using a combination of equity contributions from Sempra, short-term debt and cash on hand.

Except for the amounts paid or estimated to settle certain legal and regulatory matters, the cost estimate does not include (i) any amounts necessary to resolve claims of Individual Plaintiffs who do not agree to participate in the settlement of the Individual Plaintiff Litigation or (ii) the matters that we describe in “Civil Litigation – Unresolved Litigation” and “Regulatory Proceedings” in Note 11 of the Notes to Condensed Consolidated Financial Statements 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 for damages, restitution, civil or administrative fines or penalties, defense, settlement or other costs or remedies that may be imposed or incurred. The cost estimate also does not include certain other costs incurred by Sempra associated with defending against shareholder derivative lawsuits and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued. The costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

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We have received insurance payments for many of the categories of costs included in the cost estimate, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response to the Leak, certain legal costs and lost gas. As of June 30, 2022, we recorded the expected recovery of the cost estimate related to the Leak of $344 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra’s Condensed Consolidated Balance Sheets. This amount is exclusive of insurance retentions and $935 million of insurance proceeds we received through June 30, 2022. We intend to pursue the full extent of our insurance coverage for the costs we have incurred. Other than insurance for certain future defense costs we may incur as well as directors’ and officers’ liability, we have exhausted all of our insurance in 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. If we are not able to secure additional insurance recovery, if any costs we have recorded as an insurance receivable are not collected, if there are delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts and/or delays could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Natural Gas Storage Operations and Reliability. Natural gas withdrawn from storage is important for service reliability during peak demand periods, including peak electric generation needs in the summer and consumer heating needs in the winter. The Aliso Canyon natural gas storage facility is the largest SoCalGas storage facility and an important component of SoCalGas’ delivery system. As a result of the Leak, the CPUC has issued a series of directives to SoCalGas specifying the range of working gas to be maintained in the Aliso Canyon natural gas storage facility as well as protocols for the withdrawal of gas, to support safe and reliable natural gas service. In February 2017, the CPUC opened a proceeding pursuant to the SB 380 OII to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility while still maintaining energy and electric reliability for the region, including considering alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated.

At June 30, 2022, the Aliso Canyon natural gas storage facility had a net book value of $908 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, incur higher than expected operating costs and/or be required to make additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Any such outcome could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Franchise Agreement

In December 2021, the Los Angeles City Council awarded SoCalGas a new, 21-year natural gas franchise following an invitation for bids, which was approved and signed by the City of Los Angeles mayor in January 2022. The 21-year term consists of an initial 13-year term from the effective date, followed by an 8-year term that the City of Los Angeles has the option to terminate. Among other conditions, the new franchise agreement was subject to CPUC approval of the rates and surcharges therein for it to become effective, which SoCalGas received in March 2022. Consistent with its terms, the new agreement went into effect on May 1, 2022, until which time SoCalGas continued to serve customers located in the City of Los Angeles in accordance with the agreement that expired on December 31, 2021, by operation of law.

Sempra Texas Utilities

Oncor relies on external financing as a significant source of liquidity for its capital requirements. In the event that Oncor fails to meet its capital requirements or is unable to access sufficient capital to finance its ongoing needs, we may elect to make additional capital contributions to Oncor (as our commitments to the PUCT prohibit us from making loans to Oncor), which could be substantial and reduce the cash available to us for other purposes, increase our indebtedness and ultimately materially adversely affect our results of operations, financial condition, cash flows and/or prospects. Oncor’s ability to make distributions may be limited by factors such as its credit ratings, regulatory capital requirements, increases in its capital plan, debt-to-equity ratio approved by the PUCT and other restrictions and considerations. In addition, Oncor will not make distributions if a majority of Oncor’s independent directors or any minority member director determines it is in the best interests of Oncor to retain such amounts to meet expected future requirements.

Off-Balance Sheet Arrangement

Our investment in Oncor Holdings is a variable interest in an unconsolidated entity. We discuss variable interests in Note 1 of the Notes to Condensed Consolidated Financial Statements.

Sempra Infrastructure

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Sempra Infrastructure expects to fund capital expenditures, investments and operations in part with available funds, including credit facilities, and cash flows from operations of the Sempra Infrastructure businesses. We expect Sempra Infrastructure will require additional funding for the development and expansion of its portfolio of projects, which may be financed through a combination of funding from the parent and minority interest owners, bank financing, issuances of debt, project financing and partnering in JVs.

On June 1, 2022, we completed the sale of a 10% NCI in SI Partners to ADIA for cash proceeds of $1.7 billion. We have used a portion of the proceeds from the sale to ADIA to repay commercial paper borrowings used to repurchase $750 million in shares of our common stock ($300 million of which was completed in the fourth quarter of 2021, $200 million of which was completed in the first quarter of 2022 and $250 million of which was completed in the second quarter of 2022), and we intend to use the remaining proceeds to help fund capital expenditures at Sempra California and Sempra Texas Utilities and to further strengthen our balance sheet.

Following the closing of the ADIA transaction, Sempra, KKR and ADIA directly or indirectly own a 70%, 20%, and 10% interest, respectively, in SI Partners. The sale of NCI in SI Partners to ADIA has reduced our ownership interest in SI Partners and requires us to involve a new minority partner in making certain business decisions. Moreover, the decrease in our ownership of SI Partners also decreases our share of the cash flows, profits and other benefits these businesses currently or may in the future produce.

In the six months ended June 30, 2022, SI Partners distributed $106 million to its minority shareholder, KKR.

LNG and Net-Zero Solutions

In 2022 to date, Sempra Infrastructure has entered into the following non-binding HOAs for the negotiation and finalization of definitive SPAs with:

▪PGNiG for a 20-year term for 2 Mtpa of LNG from the proposed Cameron LNG JV liquefaction expansion project (Cameron LNG JV Phase 2 project) and 1 Mtpa from the proposed PA LNG Phase 1 project. The HOA also provides PGNiG the opportunity in 2022 to reallocate volumes from the Cameron LNG JV Phase 2 project to the PA LNG Phase 1 project.

▪INEOS Energy Trading Ltd., a subsidiary of INEOS Ltd., for a 20-year term for approximately 1.4 Mtpa of LNG from the proposed PA LNG Phase 1 project or the proposed Cameron LNG JV Phase 2 project, with amounts to be allocated between the two projects at Sempra Infrastructure’s election.

▪RWE Supply & Trading GmbH, a subsidiary of RWE AG, for a 15-year term for 2.25 Mtpa of LNG from the proposed PA LNG Phase 1 project.

▪ConocoPhillips for a 20-year term for 5 Mtpa of LNG from the proposed PA LNG Phase 1 project. The HOA is further discussed below.

The ultimate participation in and offtake from the proposed projects remain subject to negotiation and finalization of definitive agreements, among other factors, and the HOAs do not commit any party to enter into definitive agreements with respect to any of the applicable proposed projects.

Cameron LNG JV Liquefaction Expansion Project. Cameron LNG JV is developing a proposed expansion project that would add one liquefaction train with an expected maximum production capacity of approximately 6.75 Mtpa and would increase the production capacity of the existing three trains through debottlenecking activities. The Cameron LNG JV site can accommodate additional trains beyond the proposed Cameron LNG JV Phase 2 project.

Cameron LNG JV previously received major permits and FTA and non-FTA approvals associated with the potential expansion that included up to two additional liquefaction trains and up to two additional full containment LNG storage tanks. In January 2022, Cameron LNG JV filed an amendment, subject to approval by the FERC, to modify the permits to allow the use of electric drives, instead of gas turbine drives, which would reduce overall emissions. The amendment, if approved, would also change the design from a two-train gas turbine expansion to a one-train electric drive expansion along with other design enhancements that, together, are expected to result in a more cost-effective and efficient facility, while also reducing overall greenhouse gas emissions.

Sempra Infrastructure and the other Cameron LNG JV partners, namely affiliates of TotalEnergies SE, Mitsui & Co., Ltd. and Japan LNG Investment, LLC, a company jointly owned by Mitsubishi Corporation and Nippon Yusen Kabushiki Kaisha, have entered into an HOA for the potential development of the Cameron LNG JV Phase 2 project. The HOA provides a commercial framework for the proposed project, including the contemplated allocation to Sempra Infrastructure of 50.2% of the projected fourth train production capacity and 25% of the projected debottlenecking capacity from the project under tolling agreements. The HOA contemplates the remaining capacity to be allocated equally to the existing Cameron LNG JV Phase 1 customers. Sempra Infrastructure plans to sell the LNG corresponding to its allocated capacity from the proposed Cameron LNG JV Phase 2 project

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under long-term SPAs prior to making a final investment decision. The HOA is a non-binding arrangement. The ultimate participation in and offtake by Sempra Infrastructure, TotalEnergies SE, Mitsui & Co., Ltd. and Japan LNG Investment, LLC remain subject to negotiation and finalization of definitive agreements, among other factors, and the HOA does not commit any party to enter into definitive agreements with respect to the proposed Cameron LNG JV Phase 2 project.

Sempra Infrastructure, the other Cameron LNG JV partners, and Cameron LNG JV have entered into a Phase 2 Project Development Agreement under which Sempra Infrastructure, subject to certain conditions and ongoing approvals by the Cameron LNG JV board, will manage and lead the Cameron LNG JV Phase 2 project development work up to a final investment decision by Cameron LNG JV.

Cameron LNG JV, upon the unanimous approval of the Cameron LNG JV board, awarded two FEED contracts, one to Bechtel Energy Inc. and the other to a joint venture between JGC America Inc. and Zachry Industrial Inc. At the conclusion of the resulting competitive FEED process, we expect to select one contractor to be the EPC contractor for the proposed Cameron LNG JV Phase 2 project.

In connection with the execution of the Phase 2 Project Development Agreement and the award of the FEED contracts, the Cameron LNG JV board unanimously approved an expansion development budget to fund, subject to the terms of the Phase 2 Project Development Agreement, development work necessary to prepare for a potential final investment decision.

Expansion of the Cameron LNG JV liquefaction facility beyond the first three trains is subject to certain restrictions and conditions under the JV project financing agreements, including among others, scope restrictions on expansion of the project unless appropriate prior consent is obtained from the existing project lenders. Under the Cameron LNG JV equity agreements, the expansion of the project requires the unanimous consent of all the partners, including with respect to the equity investment obligation of each partner. Working under the framework established in the Phase 2 Project Development Agreement, Sempra Infrastructure is targeting completing the FEED work in the summer of 2023 and expects to be in a position to make a final investment decision shortly thereafter. The timing of when or if Cameron LNG JV will receive approval from the FERC to amend its permits and from the existing project lenders to conduct the expansion under its financing agreements is uncertain, and there is no assurance that Sempra Infrastructure will complete the necessary development work or that the Cameron LNG JV members will unanimously agree in a timely manner or at all on making a final investment decision, which, if not accomplished, would materially and adversely impact the development of the Cameron LNG JV Phase 2 project.

The development of the proposed Cameron LNG JV Phase 2 project is subject to numerous other risks and uncertainties, including securing binding customer commitments; reaching unanimous agreement with our partners to proceed; obtaining and maintaining a number of permits and regulatory approvals, including approval from the FERC for amendments to existing permits; securing certain consents under the existing financing agreements and securing sufficient new financing; negotiating and completing suitable commercial agreements, including a definitive EPC contract and definitive Cameron LNG JV tolling and governance agreements; reaching a positive final investment decision; and other factors associated with this potential investment. For a discussion of these risks, see “Part I – Item 1A. Risk Factors” in the Annual Report.

ECA LNG Liquefaction Export Projects. Sempra Infrastructure is developing two separate natural gas liquefaction export projects at its existing ECA Regas Facility. The liquefaction export projects, which are planned for development in two phases (a mid-scale project by ECA LNG Phase 1 that is under construction and a proposed large-scale project by ECA LNG Phase 2), are being developed to provide buyers with direct access to North American west coast LNG supplies. We do not expect the construction or operation of the ECA LNG Phase 1 project to disrupt operations at the ECA Regas Facility, but have planned measures to limit disruption of operations should any arise. However, construction of the proposed ECA LNG Phase 2 project would conflict with the current operations at the ECA Regas Facility, which currently has long-term regasification contracts for 100% of the regasification facility’s capacity through 2028, making the decisions on whether, when and how to pursue the ECA LNG Phase 2 project dependent in part on whether the investment in a large-scale liquefaction facility would, over the long term, be more beneficial financially than continuing to supply regasification services under our existing contracts.

In March 2019, ECA LNG received two authorizations from the DOE to export U.S.-produced natural gas to Mexico and to re-export LNG to non-FTA countries from its ECA LNG Phase 1 project, which is a one-train natural gas liquefaction facility with a nameplate capacity of 3.25 Mtpa and initial offtake capacity of approximately 2.5 Mtpa that is under construction, and its proposed ECA LNG Phase 2 project that is under development.

In April 2020, ECA LNG Phase 1 executed definitive 20-year SPAs with Mitsui & Co., Ltd. for approximately 0.8 Mtpa of LNG and with an affiliate of TotalEnergies SE for approximately 1.7 Mtpa of LNG. In December 2020, an affiliate of TotalEnergies SE acquired a 16.6% ownership interest in ECA LNG Phase 1, with Sempra Infrastructure retaining an 83.4% ownership interest. Our MOUs and/or HOAs with Mitsui & Co., Ltd., TotalEnergies SE, and ConocoPhillips, which we describe below, provide a framework for their potential offtake of LNG from, and potential acquisition of an equity interest in, ECA LNG Phase 2.

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In February 2020, we entered into an EPC contract with Technip Energies for the engineering, procurement and construction of the ECA LNG Phase 1 project. Since reaching a positive final investment decision with respect to the project in November 2020, Technip Energies has been working to construct the ECA LNG Phase 1 project. The total price of the EPC contract is estimated at approximately $1.5 billion. We estimate that capital expenditures will approximate $2.0 billion, including capitalized interest and project contingency. The actual cost of the EPC contract and the actual amount of these capital expenditures may differ, perhaps substantially, from our estimates. We expect ECA LNG Phase 1 to begin producing LNG by the end of 2024.

In December 2020, ECA LNG Phase 1 entered into a five-year loan agreement for an aggregate principal amount of up to $1.6 billion, of which $455 million was outstanding at June 30, 2022. Proceeds from the loan are being used to finance the cost of construction of the ECA LNG Phase 1 project. We discuss the details of this loan in Note 7 of the Notes to Condensed Consolidated Financial Statements in this report and in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report.

The construction of the ECA LNG Phase 1 project and the development of the potential ECA LNG Phase 2 project are subject to numerous risks and uncertainties. For Phase 1, these include maintaining permits and regulatory approvals; construction delays; securing and maintaining commercial arrangements, such as gas supply and transportation agreements; the impact of recent and proposed changes to the law in Mexico; and other factors associated with the project and its construction. For the ECA LNG Phase 2 project, these include obtaining binding customer commitments; the receipt of a number of permits and regulatory approvals; obtaining financing; negotiating and completing suitable commercial agreements, including a definitive EPC contract, equity acquisition and governance agreements, LNG sales agreements and gas supply and transportation agreements; reaching a positive final investment decision; the impact of recent and proposed changes to the law in Mexico; and other factors associated with this potential investment. In addition, as we discuss in Note 11 of the Notes to Condensed Consolidated Financial Statements, an unfavorable decision on certain property disputes or permit challenges, or an extended dispute with existing customers at the ECA Regas Facility, could materially adversely affect the development and construction of these projects and Sempra’s results of operations, financial condition, cash flows and/or prospects, including the impairment of all or a substantial portion of the capital costs invested in the projects to date. For a discussion of these risks, see “Part I – Item 1A. Risk Factors” in the Annual Report.

Port Arthur LNG Liquefaction Export Project. Sempra Infrastructure is developing a proposed natural gas liquefaction export project on a greenfield site that it owns in the vicinity of Port Arthur, Texas, located along the Sabine-Neches waterway. Sempra Infrastructure received authorizations from the DOE in August 2015 and May 2019 that collectively permit the LNG to be produced from the proposed PA LNG Phase 1 project to be exported to all current and future FTA and non-FTA countries. In February 2020, Sempra Infrastructure filed an application with the DOE to permit LNG produced from the proposed PA LNG Phase 2 project to be exported to all current and future FTA and non-FTA countries.

In April 2019, the FERC approved the siting, construction and operation of the proposed PA LNG Phase 1 project facilities, along with certain natural gas pipelines, including the Louisiana Connector and Texas Connector Pipelines, that could be used to supply feed gas to the liquefaction facility if and when the project is completed. In February 2020, Sempra Infrastructure filed a FERC application for the siting, construction and operation of the proposed PA LNG Phase 2 project, including the potential addition of up to two liquefaction trains.

In February 2020, we entered into an EPC contract with Bechtel for the proposed PA LNG Phase 1 project. The EPC contract contemplates the construction of two liquefaction trains with a nameplate capacity of approximately 13 Mtpa, two LNG storage tanks, a marine berth and associated loading facilities and related infrastructure necessary to provide liquefaction services. In December 2020, we amended and restated the EPC contract to reflect an estimated price of approximately $8.7 billion. Since we did not issue a full notice to proceed by July 15, 2021, agreement by both parties on an amendment to the EPC contract is necessary to proceed. On April 8, 2022, we entered into an agreement with Bechtel to provide a revised proposal for the EPC contract price and the EPC schedule for the proposed PA LNG Phase 1 project. Bechtel is scheduled to issue this revised proposal later this year for Sempra Infrastructure’s consideration. Any agreement on such an amendment to the EPC contract by both parties or on favorable terms to Sempra Infrastructure cannot be assured.

In July 2022, Sempra Infrastructure and ConocoPhillips entered into a non-binding HOA to develop Sempra Infrastructure’s proposed PA LNG Phase 1 project and jointly participate in other related energy infrastructure in Southeast Texas and the Pacific Coast of Mexico, including ECA LNG Phase 2. In addition to potential offtake of 5 Mtpa of LNG from the proposed PA LNG Phase 1 project, the HOA also contemplates a 30% equity investment in the proposed PA LNG Phase 1 project by ConocoPhillips and the potential for ConocoPhillips to supply additional natural gas to the proposed facility.

We are progressing the development of the proposed PA LNG Phase 1 project, taking into account market demands given the current geopolitical environment, completing certain milestones with Bechtel, executing definitive agreements for LNG offtake and equity investments, and obtaining financing. We also continue to evaluate overall opportunities to develop the entirety of the

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Port Arthur site as well as potential design changes that could reduce overall emissions, including a facility design utilizing electric drives, renewable power sourcing and other technological solutions, which may apply to any future expansions, such as the proposed PA LNG Phase 2 project.

Development of the Port Arthur LNG liquefaction export project is subject to a number of risks and uncertainties, including obtaining binding customer commitments; identifying suitable project partners; completing the required commercial agreements, such as equity acquisition and governance agreements, LNG sales agreements and gas supply and transportation agreements; completing construction contracts, including an amendment to the EPC contract with Bechtel; securing and maintaining all necessary permits and approvals; obtaining financing and incentives, such as obtaining property tax abatement; reaching a positive final investment decision; and other factors associated with the potential investment. An unfavorable outcome with respect to any of these factors could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects, including the impairment of all or a substantial portion of the capital costs invested in the project to date. For a discussion of these risks, see “Part I – Item 1A. Risk Factors” in the Annual Report.

Vista Pacifico LNG Liquefaction Export Project. Sempra Infrastructure is developing Vista Pacifico LNG, a potential natural gas liquefaction, storage, and mid-scale export facility proposed to be located in the vicinity of Topolobampo in Sinaloa, Mexico, under an MOU with the CFE, which was subsequently updated in July 2022, that contemplates the negotiation of definitive agreements that would cover development of Vista Pacifico LNG, as well as a separate natural gas regasification project in La Paz Baja California Sur, and the potential re-routing of a portion of the Guaymas-El Oro segment of the Sonora pipeline and resumption of its operations through mutual agreements between the CFE and the Yaqui tribe. The proposed LNG export terminal would be supplied with U.S. natural gas and would use excess natural gas and pipeline capacity on existing pipelines in Mexico with the intent of helping to meet growing demand for natural gas and LNG in the Mexican and Pacific markets. In November 2020, Sempra Infrastructure filed an application with the DOE to permit the export of natural gas to Mexico and for LNG produced from the proposed Vista Pacifico LNG facility to be re-exported to all current and future FTA and non-FTA countries. In April 2021, the DOE granted Vista Pacifico’s LNG export authorization application for FTA countries.

In March 2022, TotalEnergies SE and Sempra Infrastructure entered into an MOU that contemplates TotalEnergies SE potentially contracting approximately one-third of the long-term export production of the proposed Vista Pacifico LNG project and potentially participating as a minority partner in the project.

The MOUs related to the proposed Vista Pacifico LNG project are non-binding arrangements. The ultimate participation in and offtake from the proposed project remain subject to negotiation and finalization of definitive agreements, among other factors, and the MOUs do not commit any party to enter into definitive agreements with respect to the project.

The development of the potential Vista Pacifico LNG project (as well as the other projects subject to the MOU with the CFE discussed above) is subject to numerous risks and uncertainties, including securing binding customer commitments; obtaining and maintaining a number of permits and regulatory approvals; securing financing; identifying suitable project partners; negotiating and completing suitable commercial agreements, including definitive EPC contracts, equity acquisition and governance agreements, LNG sales agreements and gas supply and transportation agreements; reaching a positive final investment decision; the impact of recent and proposed changes to the law in Mexico; and other factors associated with this potential investment. For a discussion of these risks, see “Part I – Item 1A. Risk Factors” in the Annual Report.

Hackberry Carbon Sequestration Project. Sempra Infrastructure is developing the potential Hackberry Carbon Sequestration project near Hackberry, Louisiana. This proposed project under development is designed to permanently sequester carbon dioxide from the Cameron LNG JV facilities. In the third quarter of 2021, Sempra Infrastructure filed an application with the U.S. Environmental Protection Agency for a Class VI carbon injection well to advance this project.

In May 2022, Sempra Infrastructure, TotalEnergies SE, Mitsui & Co., Ltd. and Mitsubishi Corporation signed a Participation Agreement for the development of the proposed Hackberry Carbon Sequestration project. The Participation Agreement contemplates that the combined Cameron LNG JV Phase 1 and proposed Cameron LNG JV Phase 2 projects would potentially serve as the anchor source for the capture and sequestration of carbon dioxide by the proposed project. It also provides the basis for the parties to enter into a JV with Sempra Infrastructure for the Hackberry Carbon Sequestration project.

The development of the potential Hackberry Carbon Sequestration project is subject to numerous risks and uncertainties, including obtaining required consents from the Cameron LNG JV partners, securing binding customer commitments; identifying suitable project partners; obtaining and maintaining a number of permits and regulatory approvals; securing financing; negotiating and completing suitable commercial agreements, including a definitive EPC contract, and equity acquisition and governance agreements; reaching a positive final investment decision; and other factors associated with this potential investment. For a discussion of these risks, see “Part I – Item 1A. Risk Factors” in the Annual Report.

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Off-Balance Sheet Arrangements. Our investment in Cameron LNG JV is a variable interest in an unconsolidated entity. We discuss variable interests in Note 1 of the Notes to Condensed Consolidated Financial Statements.

In June 2021, Sempra provided a promissory note, which constitutes a guarantee, for the benefit of Cameron LNG JV with a maximum exposure to loss of $165 million. 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. We discuss this guarantee in Note 6 of the Notes to Condensed Consolidated Financial Statements.

In July 2020, Sempra entered into a Support Agreement, which contains a guarantee and represents a variable interest, for the benefit of CFIN with a maximum exposure to loss of $979 million. The guarantee will terminate upon full repayment of the guaranteed debt by 2039, including repayment following an event in which the guaranteed debt is put to Sempra. We discuss this guarantee in Notes 1, 6 and 9 of the Notes to Condensed Consolidated Financial Statements.

Energy Networks

Construction Projects. Sempra Infrastructure is currently constructing additional terminals for the receipt, storage, and delivery of liquid fuels in the vicinity of Puebla and Topolobampo. Sempra Infrastructure is also developing terminals for the receipt, storage, and delivery of liquid fuels in the vicinity of Manzanillo and Ensenada.

As part of an industrywide audit and investigative process initiated by the CRE to enforce fuel procurement laws, federal prosecutors conducted inspections at several refined products terminals, including Sempra Infrastructure's refined products terminal in Puebla, to confirm that the gasoline and/or diesel in storage were legally imported. During the inspection of the Puebla terminal in September 2021, a federal prosecutor took samples from all the train and storage tanks in the terminal and ordered that the facility be temporarily shut down during the pendency of the analysis of the samples and investigation, while leaving the terminal in Sempra Infrastructure’s custody. In November 2021, the CRE notified Sempra Infrastructure that it had started a process to revoke Sempra Infrastructure’s storage permit at the Puebla terminal. In December 2021, Sempra Infrastructure filed its response to the CRE. In May 2022, the CRE provided a final resolution that stopped the permit revocation process. We expect that, with this resolution, the federal prosecutors will close the investigation and the Puebla terminal will commence commercial operations in the second half of 2022.

Construction of the Topolobampo terminal was completed in May 2022, at which time commissioning activities commenced. We expect the Topolobampo terminal will commence commercial operations in the second half of 2022, subject to the receipt of pending permits.

Expected commencement dates could be delayed by worsening or extended disruptions of project construction caused by factors outside our control, including the COVID-19 pandemic. Sempra Infrastructure is continuing to monitor the impacts of the COVID-19 pandemic on cash flows and results of operations.

The ability to successfully complete major construction projects is subject to a number of risks and uncertainties. For a discussion of these risks and uncertainties, see “Part I – Item 1A. Risk Factors” in the Annual Report.

Clean Power

Construction Projects. ESJ completed construction and began commercial operations of a second, 108-MW wind power generation facility on January 15, 2022. This second wind power generation facility is fully contracted by SDG&E under a long-term PPA expiring in 2042.

In March 2022, TotalEnergies SE and Sempra Infrastructure entered into a non-binding MOU that provides a framework for cooperation in the development of North American renewable energy projects. The MOU includes the potential acquisition by Sempra Infrastructure of a target of 30% of TotalEnergies SE’s 80% equity interest in a proposed offshore wind project in California that is under development, which would result in an acquisition of 24% of the total equity interest in the project, and the potential acquisition by TotalEnergies SE of a targeted 30% equity interest in certain renewable and energy storage development projects that are under development by Sempra Infrastructure in Northern Mexico. In June 2022, Sempra Infrastructure notified TotalEnergies SE that it does not intend to participate in the proposed offshore wind project in California. The ultimate participation of TotalEnergies SE and/or Sempra Infrastructure remain subject to negotiation and finalization of definitive agreements, among other factors, and TotalEnergies SE and Sempra Infrastructure have no commitment to participate in any or all these projects unless such definitive agreements are established.

Acquisition of ESJ. As we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements, in March 2021, Sempra Infrastructure increased its ownership interest in ESJ from 50% to 100% by acquiring Saavi Energía’s 50% equity interest in ESJ.

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Legal and Regulatory Matters

See Note 11 of the Notes to Condensed Consolidated Financial Statements for discussions of the following legal and regulatory matters affecting our operations in Mexico:

Energía Costa Azul

▪Land Disputes

▪Environmental and Social Impact Permits

▪Customer Dispute

One or more unfavorable final decisions on these land and customer disputes or environmental and social impact permit 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.

Sonora Pipeline

▪Guaymas-El Oro Segment

Our investment in the Guaymas-El Oro segment of the Sonora pipeline could be subject to impairment if Sempra Infrastructure is unable to make certain repairs (which have not commenced) or re-route a portion of the pipeline (which has not been agreed to by the parties, but is subject to negotiation pursuant to a non-binding MOU and a Shareholders’ Agreement that remains subject to regulatory and corporate authorizations) and resume operations or if Sempra Infrastructure terminates the contract and is unable to obtain recovery. Any such occurrence could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Regulatory and Other Actions by the Mexican Government

▪Transmission Rates for Legacy Generation Facilities

▪Offtakers of Legacy Generation Permits

▪Amendments to Mexico’s Electricity Industry Law

▪Amendments to Mexico’s Hydrocarbons Law

Sempra Infrastructure and other parties affected by these resolutions, orders, decrees, regulations and proposed amendments to Mexican law have challenged them by filing amparo and other claims, some of which have been granted injunctive relief. The court-ordered injunctions or suspensions provide temporary relief until Mexico’s federal district court or Supreme Court ultimately resolves the amparo and other claims. An unfavorable decision on one or more of these amparo or other challenges, the potential for extended disputes, or the possibility of future reforms to the energy industry through further amendments to Mexican laws, rules or the constitution may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, may result in decreased revenues and cash flows, and may negatively impact our ability to recover the carrying values of our investments in Mexico, any of which may have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects.

SOURCES AND USES OF CASH

The following tables include only significant changes in cash flow activities for each of our registrants.

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CASH FLOWS FROM OPERATING ACTIVITIES
(Dollars in millions)
Six months ended June 30,	Sempra		SDG&E		SoCalGas
2022	$	2,364	$	1,013	$	861
2021	2,255		610		963
Change	$	109	$	403	$	(102)
Change in accounts receivable	$	165	$	7	$	195
Change in accounts payable	148		95		31
Higher net income, adjusted for noncash items included in earnings	135		94		21
Funds fully drawn against customer’s letters of credit, net of amounts applied	96
Change in customer deposits	60		18		33
Net increase in Reserve for Aliso Canyon Costs, current and noncurrent, due to $140 higher accruals offset by $88 higher payments	52				52
Change in inventory	49		4		(26)
Lower proceeds received from Insurance Receivable for Aliso Canyon	(15)				(15)
Lower distributions received from Cameron LNG JV	(145)
Change in net undercollected regulatory balancing accounts (including long-term amounts in regulatory assets)	(186)		188		(374)
Change in income taxes receivable/payable, net	(254)		12		(2)
Other	4		(15)		(17)
	$	109	$	403	$	(102)

CASH FLOWS FROM INVESTING ACTIVITIES
(Dollars in millions)
Six months ended June 30,	Sempra		SDG&E		SoCalGas
2022	$	(2,535)	$	(1,082)	$	(931)
2021	(2,588)		(1,065)		(936)
Change	$	53	$	(17)	$	5
Acquisition of 50% interest in ESJ in March 2021 for $79, net of $14 of cash and cash equivalents acquired	$	65
Decrease (increase) in capital expenditures	63		$	(18)	$	5
Contributions to Cameron LNG JV in 2022	(10)
Higher contributions to Oncor Holdings	(71)
Other	6		1
	$	53	$	(17)	$	5

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CASH FLOWS FROM FINANCING ACTIVITIES
(Dollars in millions)
Six months ended June 30,	Sempra		SDG&E		SoCalGas
2022	$	1,685	$	577	$	449
2021	(282)		206		(27)
Change	$	1,967	$	371	$	476
Higher issuances of long-term debt	$	3,663	$	1,395	$	697
Proceeds from sale of NCI to ADIA in 2022, net of $12 of transaction costs	1,719
Lower payments on long-term debt and finance leases	1,061		198
Higher issuances of short-term debt with maturities greater than 90 days	870
Equity contribution from Sempra Energy					150
(Higher) lower common dividends paid	(77)				50
Distributions to SI Partners’ minority shareholder in 2022	(106)
Higher repurchases of common stock	(438)
Higher payments for commercial paper and other short-term debt with maturities greater than 90 days	(1,172)		(375)
Change in borrowings and repayments of short-term debt, net	(3,595)		(838)		(415)
Other	42		(9)		(6)
	$	1,967	$	371	$	476

Capital Expenditures, Investments and Acquisitions

EXPENDITURES FOR PP&E, INVESTMENTS AND ACQUISITIONS
(Dollars in millions)
	Six months ended June 30,
	2022		2021
SDG&E	$	1,090	$	1,072
SoCalGas	931		936
Sempra Texas Utilities	171		100
Sempra Infrastructure	346		480
Parent and other	4		1
Total	$	2,542	$	2,589

The amounts and timing of capital expenditures and certain investments are generally subject to approvals by various regulatory and other governmental and environmental bodies, including the CPUC, the FERC and the PUCT, and various other factors described in this MD&A and in “Part I – Item 1A. Risk Factors” in the Annual Report. In 2022, we expect to make capital expenditures and investments of approximately $5.8 billion (which excludes capital expenditures that will be funded by unconsolidated entities) a decrease from the $6.2 billion projected in “Part II – Item 7. MD&A – Capital Resources and Liquidity” in the Annual Report. The decrease is primarily attributable to a delay in certain capital expenditures of approximately $300 million at SDG&E and $100 million at SoCalGas.

CRITICAL ACCOUNTING ESTIMATES

Management views certain accounting estimates as critical because their application is the most relevant, judgmental and/or material to our financial position and results of operations, and/or because they require the use of material judgments and estimates. We discuss critical accounting estimates in “Part II – Item 7. MD&A” in the Annual Report.

NEW ACCOUNTING STANDARDS

We discuss the recent accounting pronouncements that have had or may have a significant effect on our financial statements and/or disclosures in Note 2 of the Notes to Condensed Consolidated Financial Statements.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We provide disclosure regarding derivative activity in Note 8 of the Notes to Condensed Consolidated Financial Statements. We discuss our market risk and risk policies in detail in “Part II – Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in the Annual Report.

COMMODITY PRICE RISK

Sempra Infrastructure is generally exposed to commodity price risk indirectly through its LNG, natural gas pipelines and storage, and power-generating assets. In the first six months of 2022, a hypothetical 10% unfavorable change in commodity prices would have resulted in a change in the fair value of our commodity-based natural gas and electricity derivatives of $8 million at June 30, 2022 compared to $3 million at December 31, 2021.

The one-day value at risk for SDG&E and SoCalGas’ commodity positions were $11 million and negligible, respectively, at June 30, 2022 compared to $5 million and $1 million, respectively, at December 31, 2021.

INTEREST RATE RISK

The table below shows the nominal amount of our debt:

NOMINAL AMOUNT OF DEBT(1)
(Dollars in millions)
	June 30, 2022						December 31, 2021
	Sempra		SDG&E		SoCalGas		Sempra		SDG&E		SoCalGas
Short-term:
Sempra California	$	—	$	—	$	—	$	1,161	$	776	$	385
Other	955		—		—		2,310		—		—
Long-term:
Sempra California fixed-rate	$	12,559	$	7,400	$	5,159	$	10,876	$	6,417	$	4,459
Sempra California variable-rate	700		400		300		300		—		300
Other fixed-rate	10,218		—		—		8,591		—		—
Other variable-rate	455		—		—		341		—		—

(1)    After the effects of interest rate swaps. Before the effects of acquisition-related fair value adjustments and reductions for unamortized discount and debt issuance costs, and excluding finance lease obligations.

An interest rate risk sensitivity analysis measures interest rate risk by calculating the estimated changes in earnings that would result from a hypothetical change in market interest rates. Earnings are affected by changes in interest rates on short-term debt and variable-rate long-term debt. If weighted-average interest rates on short-term debt outstanding at June 30, 2022 increased or decreased by 10%, the change in earnings over the 12-month period ending June 30, 2023 would be approximately $2 million. If interest rates increased or decreased by 10% on all variable-rate long-term debt at June 30, 2022, after considering the effects of interest rate swaps, the change in earnings over the 12-month period ending June 30, 2023 would be approximately $2 million.

FOREIGN CURRENCY AND INFLATION RATE RISK

We discuss our foreign currency and inflation exposures in “Part I – Item 2. MD&A – Impact of Foreign Currency and Inflation Rates on Results of Operations” in this report and in “Part II – Item 7. MD&A – Impact of Foreign Currency and Inflation Rates on Results of Operations” in the Annual Report. At June 30, 2022, there were no significant changes to our exposure to foreign currency rate risk since December 31, 2021.

In 2022, SDG&E and SoCalGas have experienced inflationary pressures from increases in various costs, including the cost of natural gas, electric fuel and purchased power, labor, materials and supplies, as well as availability of labor and materials. Sempra Texas Utilities has experienced increased costs of labor and materials and does not have specific regulatory mechanisms that allow for recovery of higher costs due to inflation. If such costs were to continue to be subject to significant inflationary pressures and we are not able to fully recover such higher costs in rates or there is a delay in recovery, these increased costs may have a significant effect on our results of operations, financial condition, cash flows and/or prospects.

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Sempra Infrastructure has experienced inflationary pressures from increases in various costs, including the cost of labor, materials and supplies. Sempra Infrastructure generally secures long-term contracts that are U.S. dollar-denominated or referenced and are periodically adjusted for market factors, including inflation, and Sempra Infrastructure generally enters into lump-sum contracts for its large construction projects in which much of the risk during construction is absorbed or hedged by the EPC contractor. If additional costs were to become subject to significant inflationary pressures, we may not be able to fully recover such higher costs through contractual adjustments for inflation, which may have a significant effect on our results of operations, financial condition, cash flows and/or prospects.

ITEM 4. CONTROLS AND PROCEDURES

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

Sempra, SDG&E and SoCalGas maintain disclosure controls and procedures designed to ensure that information required to be disclosed in their respective reports filed or submitted under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and is accumulated and communicated to the management of each company, including each respective principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure. In designing and evaluating these controls and procedures, the management of each company recognizes that any system of controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives; therefore, the management of each company applies judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Under the supervision and with the participation of the principal executive officers and principal financial officers of Sempra, SDG&E and SoCalGas, each such company’s management evaluated the effectiveness of the design and operation of its disclosure controls and procedures as of June 30, 2022, the end of the period covered by this report. Based on these evaluations, the principal executive officers and principal financial officers of Sempra, SDG&E and SoCalGas concluded that their respective company’s disclosure controls and procedures were effective at the reasonable assurance level as of such date.

INTERNAL CONTROL OVER FINANCIAL REPORTING

There have been no changes in Sempra’s, SDG&E’s or SoCalGas’ internal control over financial reporting during the most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, any such company’s internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We are not party to, and our property is not the subject of, any material pending legal proceedings (other than ordinary routine litigation incidental to our businesses) except for the matters (1) described in Notes 10 and 11 of the Notes to Condensed Consolidated Financial Statements in this report and in Notes 15 and 16 of the Notes to Consolidated Financial Statements in the Annual Report, or (2) referred to in “Part I – Item 2. MD&A” in this report or in “Part I – Item 1A. Risk Factors” or “Part II – Item 7. MD&A” in the Annual Report.

ITEM 1A. RISK FACTORS

When evaluating our company and its subsidiaries and any investment in our or their securities, you should consider carefully the risk factors and all other information contained in this report and in the other documents we file with the SEC (including those

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filed subsequent to this report), including the factors discussed in “Part I – Item 2. MD&A” in this report and “Part I – Item 1A. Risk Factors” and “Part II – Item 7. MD&A” in the Annual Report. Any of the risks and other information discussed in this report or any of the risk factors discussed in “Part I – Item 1A. Risk Factors” or “Part II – Item 7. MD&A” in the Annual Report, as well as additional risks and uncertainties not currently known to us or that we currently deem to be immaterial, could materially adversely affect our results of operations, financial condition, cash flows, prospects and/or the trading prices of our securities or those of our subsidiaries.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS

On July 6, 2020, our board of directors authorized the repurchase of shares of our common stock at any time and from time to time in an aggregate amount not to exceed the lesser of $2 billion or amounts spent to purchase no more than 25 million shares. This repurchase authorization was publicly announced on August 5, 2020 and has no expiration date. As of August 4, 2022, a maximum of $1.25 billion and no more than 19,632,529 shares may yet be purchased under this repurchase authorization.

The following table sets forth information about our common stock repurchase activity for the three months ended June 30, 2022:

PURCHASES OF EQUITY SECURITIES
(Dollars in millions, except per share amounts)
	Total number of shares purchased(1)	Average price paid per share(1)		Total number of shares purchased as part of publicly announced plans or programs(1)	Maximum dollar value of shares that may yet be purchased under the plans or programs
April 1, 2022 - April 30, 2022	1,471,957	$	169.84	1,471,957	$	1,250

(1)    On April 6, 2022, we entered into an ASR program under which we prepaid $250 to repurchase shares of our common stock in a share forward transaction. The total number of shares purchased was determined by dividing the $250 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.

We may also, from time to time, purchase shares of our common stock to which participants would otherwise be entitled from long-term incentive plan participants who elect to sell a sufficient number of shares in connection with the vesting of RSUs and stock options in order to satisfy minimum statutory tax withholding requirements.

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ITEM 6. EXHIBITS

The exhibits listed below relate to each registrant as indicated. Unless otherwise indicated, the exhibits that are incorporated by reference herein were filed under File Number 1-14201 (Sempra Energy), File Number 1-40 (Pacific Lighting Corporation), File Number 1-03779 (San Diego Gas & Electric Company) and/or File Number 1-01402 (Southern California Gas Company).

EXHIBIT INDEX
			Incorporated by Reference
Exhibit Number	Exhibit Description	Filed or Furnished Herewith	Form	Exhibit or Appendix	Filing Date
EXHIBIT 3 -- ARTICLES OF INCORPORATION AND BYLAWS
Sempra Energy
3.1	Amended and Restated Articles of Incorporation of Sempra Energy effective May 23, 2008.		10-K	3.1	02/27/20
3.2	Bylaws of Sempra Energy (as amended through April 14, 2020).		8-K	3.1	04/14/20
3.3	Certificate of Determination of Preferences of the 6% Mandatory Convertible Preferred Stock, Series A, of Sempra Energy (including the form of certificate representing the 6% Mandatory Convertible Preferred Stock, Series A), filed with the Secretary of State of the State of California and effective January 5, 2018.		8-K	3.1	01/09/18
3.4	Certificate of Determination of Preferences of the 6.75% Mandatory Convertible Preferred Stock, Series B, of Sempra Energy (including the form of certificate representing the 6.75% Mandatory Convertible Preferred Stock, Series B), filed with the Secretary of State of the State of California and effective July 11, 2018.		8-K	3.1	07/13/18
3.5	Certificate of Determination of Preferences of 4.875% Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, Series C, of Sempra Energy (including the form of certificate representing the 4.875% Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, Series C), filed with the Secretary of State of the State of California and effective June 11, 2020.		8-K	3.1	06/15/20
San Diego Gas & Electric Company
3.6	Amended and Restated Articles of Incorporation of San Diego Gas & Electric Company effective August 15, 2014.		10-K	3.4	02/26/15
3.7	Bylaws of San Diego Gas & Electric Company (as amended through October 26, 2016).		10-Q	3.1	11/02/16
Southern California Gas Company
3.8	Restated Articles of Incorporation of Southern California Gas Company effective October 7, 1996.		10-K	3.01	03/28/97
3.9	Bylaws of Southern California Gas Company (as amended through January 30, 2017).		8-K	3.1	01/31/17
EXHIBIT 10 -- MATERIAL CONTRACTS
Sempra Energy / Southern California Gas Company
10.1	First Amendment to Master Agreement to Resolve JCCP No. 4861 Private Party Claims, dated as of July 15, 2022, by and among Sempra Energy, Southern California Gas Company, and the plaintiffs’ law firms listed on the signature pages thereto.	X

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EXHIBIT INDEX (CONTINUED)
Exhibit Number	Exhibit Description	Filed or Furnished Herewith
EXHIBIT 31 -- SECTION 302 CERTIFICATIONS
Sempra Energy
31.1	Certification of Sempra Energy’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.2	Certification of Sempra Energy’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
San Diego Gas & Electric Company
31.3	Certification of San Diego Gas & Electric Company’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.4	Certification of San Diego Gas & Electric Company’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
Southern California Gas Company
31.5	Certification of Southern California Gas Company’s Principal Executive Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
31.6	Certification of Southern California Gas Company’s Principal Financial Officer pursuant to Rules 13a-14 and 15d-14 of the Securities Exchange Act of 1934.	X
EXHIBIT 32 -- SECTION 906 CERTIFICATIONS
Sempra Energy
32.1	Certification of Sempra Energy’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.2	Certification of Sempra Energy’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X
San Diego Gas & Electric Company
32.3	Certification of San Diego Gas & Electric Company’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.4	Certification of San Diego Gas & Electric Company’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X
Southern California Gas Company
32.5	Certification of Southern California Gas Company’s Principal Executive Officer pursuant to 18 U.S.C. Sec. 1350.	X
32.6	Certification of Southern California Gas Company’s Principal Financial Officer pursuant to 18 U.S.C. Sec. 1350.	X

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EXHIBIT INDEX (CONTINUED)
Exhibit Number	Exhibit Description	Filed or Furnished Herewith
EXHIBIT 101 -- INTERACTIVE DATA FILE
101.INS	XBRL Instance Document - the instance document does not appear in the Interactive Data file because its XBRL tags are embedded within the Inline XBRL document.	X
101.SCH	Inline XBRL Taxonomy Extension Schema Document.	X
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document.	X
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document.	X
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document.	X
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document.	X
EXHIBIT 104 -- COVER PAGE INTERACTIVE DATA FILE
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

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SIGNATURES

Sempra Energy:
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
	SEMPRA ENERGY, (Registrant)
Date: August 4, 2022	By: /s/ Peter R. Wall
	Peter R. Wall
	Senior Vice President, Controller and Chief Accounting Officer (Duly Authorized Officer)

San Diego Gas & Electric Company:
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
	SAN DIEGO GAS & ELECTRIC COMPANY, (Registrant)
Date: August 4, 2022	By: /s/ Valerie A. Bille
	Valerie A. Bille
	Vice President, Controller and Chief Accounting Officer (Duly Authorized Officer)

Southern California Gas Company:
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
	SOUTHERN CALIFORNIA GAS COMPANY, (Registrant)
Date: August 4, 2022	By: /s/ Mia L. DeMontigny
	Mia L. DeMontigny
	Senior Vice President, Chief Financial Officer and Chief Accounting Officer (Duly Authorized Officer)

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EX-10.1

Exhibit 10.1

FIRST AMENDMENT
TO
MASTER AGREEMENT TO RESOLVE JCCP No. 4861 PRIVATE PARTY CLAIMS

This First Amendment to Master Agreement to Resolve JCCP No. 4861 Private Party Claims (this “Amendment”), dated as of July 15, 2022 (the “First Amendment Date”), is entered into by and between (i) Defendant Southern California Gas Company, (ii) Defendant Sempra Energy, and (iii) the plaintiff law firms listed on the signature pages hereto under the heading “Plaintiffs’ Counsel” (each individual law firm, a “Plaintiffs’ Counsel Firm,” and such firms collectively “Plaintiffs’ Counsel”) on behalf of their respective Eligible Plaintiffs. Defendants and Plaintiffs’ Counsel, on behalf of all Eligible Plaintiffs they represent, are referred to herein collectively as the “Parties” and individually as a “Party.”

RECITALS

WHEREAS, on September 26, 2021, the Parties executed and delivered that certain Master Agreement to Resolve JCCP No. 4861 Private Party Claims(the “Agreement”), a copy of which is attached to this Amendment as Exhibit A;

WHEREAS, pursuant to Section 9.2 of the Agreement, the Agreement may be amended by a written instrument signed by each of the Parties;

WHEREAS, the Parties desire to (i) amend and clarify any ambiguity surrounding the timing of the payment of the Final Settlement Amount following the CP Satisfaction Date, the satisfaction of the Conditions Precedent and any waiver by Defendants of the Conditions Precedent, and (ii) allow sufficient time for the Conditions Precedent set forth in Section 4.1 of the Agreement, as amended by this Amendment, to be satisfied; and

WHEREAS, the Parties have determined it is in the mutual interest of each Party to the Agreement to amend and clarify certain terms of the Agreement as set forth in this Amendment.

NOW, THEREFORE, for consideration duly received, the adequacy, receipt and sufficiency of which each Party hereby acknowledges, the Parties agree as follows:

AGREEMENT

1.1Undefined Terms. Any undefined capitalized terms used in this Amendment and not otherwise defined shall have the meaning ascribed to such terms in the Agreement.

1.2Amendments to the Agreement.

(a)The definition of CP Satisfaction Date Deadline at Section 2.12 of the Agreement is hereby amended to replace the phrase “June 1, 2022” with “August 15, 2022 at 6:00 p.m. Pacific Daylight Time”.

(b)The definition of Termination Date at Section 2.46 of the Agreement is hereby amended to replace the phrase “the forty fifth (45th) day after the CP Satisfaction Date Deadline” with “August 22, 2022 at 6:00 p.m. Pacific Daylight Time”.

(c)Section 4.1(ii) of the Agreement is hereby amended to replace the phrase “the Court has approved, directly or through a duly appointed special master or referee, all Settling Minors’ Compromise Petitions with respect to all such Minor Eligible Plaintiffs” with “Plaintiffs shall have filed with the Court petitions for approval of the Settling Minors’ Compromises with respect to all such Minor Eligible Plaintiffs together with proposed orders approving such Settling Minors’ Compromises”.

(d)Section 4.1(xi) of the Agreement is hereby amended to replace the entire sentence with “Proposed orders of dismissal for the dismissals contemplated by Section 5.3 shall have been filed with the Court

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pursuant to a stipulation and/or a request for the issuance of an OSC Re: Dismissal filed by the Defendants in accordance with a process suggested by the Court”.

(e)The first sentence of Section 4.2 of the Agreement is hereby amended and replaced in its entirety with the following: “In exchange for the good and valuable consideration and terms set forth in this Agreement, subject to the satisfaction, or waiver by Defendants (in Defendants’ sole and absolute discretion), of the Conditions Precedent, Defendants agree to pay an amount equal to the Maximum Settlement Amount less the Reduction (which Reduction is calculated pursuant to Section 2.39 and Section 5.11) (such amount, the “Final Settlement Amount”).”

(f)The first sentence of Section 4.4 of the Agreement is hereby amended and replaced in its entirety with the following:

Upon either (i) the satisfaction of the Conditions Precedent on or prior to the CP Satisfaction Date Deadline or (ii) the waiver by Defendants (in Defendants’ sole and absolute discretion) of the Conditions Precedent on or prior to the Termination Date, Defendants shall, subject to Section 5.11 with respect to the Section 5.11 Adjustment relating to Minor Additional Plaintiffs, transfer no later than August 30, 2022 ninety three percent (93%) of the Final Settlement Amount (calculated as of August 15, 2022) in immediately available funds to a trust intended to be treated as a qualified settlement fund established pursuant to § 468B of the Internal Revenue Code of 1986, as amended, and United States Treasury Regulation § 1.468B-1 et seq (the “QSF Account”).

(g)The first sentence of Section 4.5 is hereby amended and replaced in its entirety with the following: “In accordance with Case Management Order No.6 (“CMO 6”) issued in the JCCP, Defendants shall withhold seven percent (7%) of the Final Settlement Amount (calculated as of August 15, 2022) in order to pay the assessments for the “Fee Fund” and “Cost Fund” established in accordance with CMO 6 (the “CMO 6 Withholding”).”

(h)A new Section 5.11 of the Agreement shall be added to the Agreement and shall read as follows:

“5.11    Additional Plaintiffs. The Parties agree that Plaintiffs’ Counsel shall use best efforts to obtain from all individuals who filed a complaint after September 1, 2021 and no later than July 10, 2022, and excluding any complaint filed on behalf of a plaintiff currently listed on the July 12, 2022 Draft Attachment E , which such individuals are listed on Attachment I to this Agreement (each an “Additional Plaintiff” and collectively, the “Additional Plaintiffs”), fully executed Individual Releases prior to August 15, 2022. If a fully executed Individual Release from an Additional Plaintiff is submitted in accordance with Section 6.3 prior to August 15, 2022 and the Final Settlement Amount is paid in accordance with Section 4.1, the Parties agree that (i) each Additional Plaintiff’s Individual Release shall be released to Defendants together with all other Individual Releases in accordance with Section 4.3, (ii) the amount of the Reduction, as calculated in accordance with Sections 2.39 and 4.2, subject to the remaining provisions of this Section 5.11 with respect to Minor Additional Plaintiffs, will be further reduced by an amount equal to (A) $50,000 multiplied by (B) the total number of Additional Plaintiffs who have delivered Individual Releases in accordance with this Section 5.11, and (iii) all Additional Plaintiffs whose Individual Releases are released to Defendants will be deemed Eligible Plaintiffs for all purposes under this Agreement following Defendants’ payment of the Final Settlement Amount (such calculation, the “Section 5.11 Adjustment”). Notwithstanding the foregoing provisions of this Section 5.11, or anything in Section 4.4, or any other provision of the Agreement to the contrary, with respect to that portion of the Section 5.11 Adjustment (if any) with respect to Additional Plaintiffs who are minors (each such minor a “Minor Additional Plaintiff”), the Section 5.11 Adjustment of the Final Settlement Amount with respect to such Minor Additional Plaintiff shall be calculated and paid as follows: (1) only Minor Additional Plaintiffs whom the Court has approved, directly or through a duly appointed special master or referee, all Settling Minors’ Compromise Petitions with respect to all such Minor Additional Plaintiffs, and whom have executed Individual Releases in accordance with this Section 5.11, in each case, on or before October 1, 2022, shall be eligible for the Section 5.11 Adjustment; and (2) the Section 5.11 Adjustment with respect to such Minor Additional Plaintiffs who meet the criteria in Section 5.11(1) shall be paid by Defendants on October 5, 2022, subject to the CMO 6 Withholding requirements set forth in Section 4.5. Defendants shall have no obligation to make any additional payments with respect to

2

Minor Additional Plaintiffs who do not meet each of the criteria set forth in Section 5.11(1) on or before October 1, 2022. If a fully executed Individual Release from an Additional Plaintiff is submitted in accordance with this Section 5.11 but the Agreement is terminated in accordance with Section 4.6, such Individual Release shall be deemed null and void together with all other Individual Releases. Within fourteen (14) days of the transfer of the Section 5.11 Adjustment with respect to any Minor Additional Plaintiffs, Plaintiffs’ Counsel shall file with the Court executed requests for dismissal with prejudice of all Claims of the Releasors in their entirety against Defendants. Plaintiffs’ Counsel shall take all necessary steps to work with the Court to ensure prompt entry of such dismissals.

With respect to the calculation of the total Reduction pursuant to Section 2.39 as modified by the Section 5.11 Adjustment described above, and by way of example only, if there are only 35,000 Eligible Plaintiffs identified on Updated Attachment E, and if only 34,500 Eligible Plaintiffs execute and deliver an Individual Release, and if there are ten (10) Settling EN Plaintiffs identified pursuant to Section 5.8, then the amount of the Reduction calculated pursuant to Section 2.39 shall equal: ($50,000 x 717) + ($50,000 x 500) – ($50,000 x 10) = $60,350,000. The Reduction is then further modified by the Section 5.11 Adjustment described in Section 5.11 as follows: if there are twenty (20) Additional Plaintiffs who are not minors who deliver Individual Releases in accordance with this Section 5.11, then the amount of the Reduction shall be further reduced as follows $60,350,000 - ($50,000 x 20) = $59,350,000. In addition, if seven (7) Minor Additional Plaintiffs meet each of the criteria set forth in Section 5.11(1) on or before October 1, 2022, then the amount of the Reduction shall be further reduced as follows $59,350,00 – ($50,000 x 7) = $59,000,000, which $59,000,000 will be the Reduction amount used to calculate the Final Settlement Amount for all purposes of this Agreement, and Defendants shall make the final Section 5.11 Adjustment payment of $350,000 to the QSF Account on October 5, 2022.

(i)Section 9.14 of the Agreement is hereby amended to add the following at the end of the Section:

“No later than August 15, 2022, Plaintiffs’ Counsel agrees to deliver to Defendants a complete update to the report previously delivered Defendants in accordance with Section 6.6, which such updated report shall be current as of August 10, 2022. From and after the CP Satisfaction Date, Plaintiffs’ Counsel further agrees to use best efforts to finalize all dismissals and releases including, without limitation, the approval of all Settling Minors’ Compromises.”

(j)Section 9.15 of the Agreement is hereby amended to add “Attachment I – Additional Plaintiffs” as the last sentence of the Section.

(k)The Agreement is hereby amended to add the Attachment I – Additional Plaintiffs that is attached to this Amendment as an attachment to the Agreement.

1.3Plaintiffs’ Counsel Representations. Plaintiffs’ Counsel represent and warrant that collectively they represent at least eighty (80) percent of Eligible Plaintiffs, and that they have the authority under Case Management Order No. 2 to enter into this Amendment. This Amendment has been duly authorized, executed and delivered by or on behalf of themselves. Upon execution and delivery, this Amendment constitutes the legal, valid, and binding obligation of the Plaintiffs’ Counsel, enforceable against such persons in accordance with its terms, except as such enforceability may be limited by applicable bankruptcy, insolvency or similar laws affecting creditors’ rights generally, by rules of professional responsibility in applicable jurisdictions governing the professional conduct of individual lawyers of Plaintiffs’ Counsel reflected on the signature page(s) of this Amendment, and by general equitable principles.

1.4Defendants’ Representations. This Amendment has been duly authorized, executed, and delivered by or on behalf of the Defendants. Upon execution and delivery, this Amendment constitutes the legal, valid, and binding obligation of such Defendants, enforceable against such Defendants in accordance with its

3

terms, except as such enforceability may be limited by applicable bankruptcy, insolvency or similar laws affecting creditors’ rights generally and by general equitable principles.

1.5Governing Law. This Amendment shall be governed by and construed in accordance with the laws of the state of California.

1.6Waiver of Inconsistent Provisions of Law; Severability. To the fullest extent permitted by applicable law, each Party waives any provision of law (including the common law) that renders any provision of this Amendment invalid, illegal, or unenforceable in any respect. If any provision of this Amendment is held to be unenforceable, this Amendment shall be considered divisible, and such provision shall be deemed inoperative to the extent it is deemed unenforceable, and in all other respects this Amendment shall remain in full force and effect.

1.7Amendments and Alterations; Agreement Remains In Full Force and Effect. This Amendment may not be altered, amended, waived, modified or otherwise changed in any respect or particular whatsoever, except by a writing duly executed by authorized representatives of the Parties. In the event of any conflict between the terms of the Agreement (prior the execution of this Amendment) and the terms of this Amendment, the terms of this Amendment shall prevail. All the provisions of this Amendment shall be deemed fully incorporated into the Agreement and made a part thereof. Except as specifically set forth in this Amendment, the terms and provisions of the Agreement shall remain unmodified and in full force and effect.

1.8Headings. The headings used herein are intended for convenience of reference only and are not intended to be a part of, or to affect the meaning or interpretation of, this Amendment.

1.9Entire Agreement and Construction. The Agreement (as amended by this Amendment) constitutes the entire agreement between the Parties and supersede all other prior or contemporaneous agreements and understandings between the Parties, whether written or oral, with respect to such extension. This Amendment may be amended or modified only by a written instrument executed by the Parties. The Parties understand and agree that each and every term and condition of this Amendment has been mutually negotiated, prepared and drafted, and if at any time the Parties desire or are required to interpret or construe any such term or condition or any agreement or instrument subject thereto, no consideration shall be given to the issue of which Party actually prepared, drafted or requested any term or condition.

1.10Electronic Signatures and Counterparts. This Amendment to the extent signed and delivered electronically or by facsimile, shall be treated in all manner and respects as an original amendment to the Agreement, and shall be considered to have the same binding legal effect as if it were the original signed version thereof, delivered in person. This Amendment may be executed in any number of counterparts, each of which shall be an original and all of which shall constitute one and the same instrument.

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]

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IN WITNESS WHEREOF, the Parties have executed and delivered this Amendment as of the First Amendment Date.

DEFENDANTS:

SOUTHERN CALIFORNIA GAS COMPANY	SEMPRA ENERGY
/s/ David J. Barrett	/s/ Peter R. Wall
Name: David J. Barrett	Name: Peter R. Wall
Title: VP & General Counsel	Title: Senior Vice President, Controller & CAO
Date: July 14, 2022	Date: July 14, 2022

APPROVED AS TO FORM AND CONTENT ONLY:

O'MELVENY & MYERS LLP	MORGAN, LEWIS & BOCKIUS LLP
/s/ Sabrina H Strong	/s/ James J. Dragna
Name: Sabrina H Strong	Name: James J. Dragna
Title: Partner	Title: Attorney
Date: July 15, 2022	Date: July 15, 2022

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]

[Signature Page to First Amendment]

PLAINTIFFS' COUNSEL:
/s/ Brian Panish	/s/ Raymond P. Boucher
Name: Brian Panish	Name: Raymond P. Boucher
Date: 07/14/2022	Date: 07/15/2022
Panish, Shea & Boyle LLP (on its own behalf and	Boucher LLP
on behalf of Kenneth T. Haan & Associates)	Raymond Boucher, Esq. (ray@boucher.la)
Brian Panish, Esq. (panish@psblaw.com)	Maria Weitz, Esq. (weitz@boucher.la)
Jesse Creed, Esq. (creed@psblaw.com)	21600 Oxnard Street, Suite 600
11111 Santa Monica Boulevard, Suite 700	Woodland Hills, CA 91367
Los Angeles, CA 90025	Phone: (818) 340-5400
Phone: (310) 477-1700	Fax: (818) 340-5401
Fax: (310) 477-1699
/s/ Patricia K. Oliver	/s/ Paul R. Kiesel
Name: Patricia K. Oliver	Name: Paul R. Kiesel
Date: 7/14/2022	Date: 07/14/2022
Parris Law Firm (on its own behalf and on behalf	Kiesel Law LLP (on its own behalf and on behalf
of Kenneth T. Haan & Associates)	of Keosian Law LLP)
R. Rex Parris, Esq. (rrparris@parrislawyers.com)	Paul Kiesel, Esq.
43364 10th Street West	Mariana McConell, Esq.
Lancaster, CA 93534	8648 Wilshire Blvd.
Phone: (661) 949-2595	Beverly Hills, CA 90211
Fax: (661) 949-7524	Phone: (310) 854.4444
	Fax: (619) 525-7672
/s/ Robin L. Greenwald	/s/ Frank Petosa
Name: Robin L. Greenwald	Name: Frank Petosa
Date: 07/15/2022	Date: 7/14/2022
Weitz & Luxenberg, P.C.	Morgan & Morgan (on its own behalf and on
Robin Greenwald, Esq.	behalf of Kenneth T. Haan & Associates)
(rgreenwald@weitzlux.com)	Frank Petosa, Esq. (fpetosa@forthepeople.com)
1880 Century Park East, Suite 700	8151 Peters Road, 4th Floor
Los Angeles, CA 90067	Plantation, FL 33324
Phone: (310) 247-0921	Phone: (954) 318-0268
Fax: (310) 786-9927	Fax: (954) 327-3018

[Signature Page to First Amendment]

/s/ Roland Tellis	/s/ Gary A. Praglin
Name: Roland Tellis	Name: Gary A. Praglin
Date: 07/14/2022	Date: 07/14/2022
Baron & Budd P.C.	Cotchett, Pitre & McCarthy LLP
Roland Tellis, Esq. (rtellis@baronbudd.com)	Frank Pitre, Esq. (fpitre@cpmlegal.com)
15910 Ventura Blvd., Suite 1600	Gray Praglin, Esq. (gpraglin@cpmlegal.com)
Encino, CA 91436	2716 Ocean Park Boulevard, Suite 3088
Phone: (818) 839-2333	Santa Monica, CA 90405
Phone: (818) 986-9698	Phone: (310) 392-2008
	Fax: (310) 392-0111
/s/ Andrew Jacobson	/s/ Alan Schimmel
Name: Andrew Jacobson	Name: Alan Schimmel
Date: 07/15/2022	Date: 07/15/2022
Engstrom, Lipscomb & Lack	Schimmel & Parks
Walter Lack, Esq. (wlack@elllaw.com)	Alan Schimmel, Esq.
10100 Santa Monica Boulevard, 12th Floor	(aischimmel@spattorneys.com)
Los Angeles, CA 90067	15303 Ventura Boulevard, Suite 650
Phone: (310) 552-3800	Sherman Oaks, CA 91403
Fax: (310) 552-9434
/s/ James Frantz
Name: James Frantz
Date: 07/15/2022
Frantz Law Group, APLC
James Frantz, Esq. (jpf@frantzlawgroup.com)
2029 Century Park East, Suite 400
Los Angeles, CA 90067
Phone: (323) 425-8138
Fax: (619) 525-7672

[Signature Page to First Amendment]

ATTACHMENT I – ADDITIONAL PLAINTIFFS

Plaintiff Name	Name of Complaint	Case No.	Filing Date of Complaint
Afaryan, Roy	Afaryan	22STCV18777	6/7/2022
Ajefmian, Raffi	Afaryan	22STCV18777	6/7/2022
Ajemian, Andre	Afaryan	22STCV18777	6/7/2022
Akhoain, Andrew	Afaryan	22STCV18777	6/7/2022
Akhoain,Christian	Afaryan	22STCV18777	6/7/2022
Barrios, Andrew	Afaryan	22STCV18777	6/7/2022
Chavez, Nathan	Afaryan	22STCV18777	6/7/2022
Choudhary, Dev	Afaryan	22STCV18777	6/7/2022
Choudhary, Tara	Afaryan	22STCV18777	6/7/2022
Davydov, Edward	Parraz	22STCV07391	3/1/2022
Debiasse, Eleanor	Afaryan	22STCV18777	6/7/2022
Debiasse, Miller	Afaryan	22STCV18777	6/7/2022
DeFrank, Antonio	Afaryan	22STCV18777	6/7/2022
Eagle, Richard	Afaryan	22STCV18777	6/7/2022
Eagle, Zachary	Afaryan	22STCV18777	6/7/2022
Eghrari, Monireh	Eghrari	21STCV43848	12/1/2021
Eshraghi, Desiree	Parraz	22STCV07391	3/1/2022
Estrada, Natalie	Afaryan	22STCV18777	6/7/2022
Estrada, Sofia	Afaryan	22STCV18777	6/7/2022
Foroughi, Emma	Parraz	22STCV07391	3/1/2022
Grodzen, Brandon	Parraz	22STCV07391	3/1/2022
Guzman, Adrianna	Afaryan	22STCV18777	6/7/2022
Jackson, Alexander	Afaryan	22STCV18777	6/7/2022
Judice, Bernardo	Afaryan	22STCV18777	6/7/2022
Judice, Luanna	Afaryan	22STCV18777	6/7/2022
Judice, Maria	Afaryan	22STCV18777	6/7/2022
Kaplan, Kyle	Parraz	22STCV07391	3/1/2022
Khatchik, Andre	Parraz	22STCV07391	3/1/2022
Kisch, William	Parraz	22STCV07391	3/1/2022
Kubler, Daniel	Afaryan	22STCV18777	6/7/2022
Kwon, Madison	Kwon	21STCV40079	11/1/2021
Levine, Rachel	Levine, Rachel	22STCV18448	6/6/2022
Lind, Rebecca	Afaryan	22STCV18777	6/7/2022
Mitchell, Zachary	Afaryan	22STCV18777	6/7/2022
O'Rourke, Eion	Afaryan	22STCV18777	6/7/2022
O'Rourke, Greyson	Afaryan	22STCV18777	6/7/2022
Parraz, Patrick J.	Parraz	22STCV07391	3/1/2022
Perceleanu, Audrey	Afaryan	22STCV18777	6/7/2022
Piskoulian, Angelina	Afaryan	22STCV18777	6/7/2022
Piskoulian, David	Afaryan	22STCV18777	6/7/2022
Piskoulian, Juliana	Afaryan	22STCV18777	6/7/2022
Skeggs, Abigail	Afaryan	22STCV18777	6/7/2022
Skeggs, Quinten	Afaryan	22STCV18777	6/7/2022
Stefano, Nicholas	Afaryan	22STCV18777	6/7/2022
Whelan, Brenna	Parraz	22STCV07391	3/1/2022

Attachment I

Exhibit A to the First Amendment
Copy of Master Agreement to Resolve JCCP No. 4861 Private Party Claims

[See attached]

Exhibit A

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, J. Walker Martin, certify that:

1.    I have reviewed this report on Form 10-Q of Sempra Energy;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ J. Walker Martin
	J. Walker Martin
	Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, Trevor I. Mihalik, certify that:

1.    I have reviewed this report on Form 10-Q of Sempra Energy;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ Trevor I. Mihalik
	Trevor I. Mihalik
	Chief Financial Officer

EX-31.3

EXHIBIT 31.3

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, Caroline A. Winn, certify that:

1.    I have reviewed this report on Form 10-Q of San Diego Gas & Electric Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ Caroline A. Winn
	Caroline A. Winn
	Chief Executive Officer

EX-31.4

EXHIBIT 31.4

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, Bruce A. Folkmann, certify that:

1.    I have reviewed this report on Form 10-Q of San Diego Gas & Electric Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ Bruce A. Folkmann
	Bruce A. Folkmann
	Chief Financial Officer

EX-31.5

EXHIBIT 31.5

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, Scott D. Drury, certify that:

1.    I have reviewed this report on Form 10-Q of Southern California Gas Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ Scott D. Drury
	Scott D. Drury
	Chief Executive Officer

EX-31.6

EXHIBIT 31.6

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO RULES 13a-14 AND 15d-14

I, Mia L. DeMontigny, certify that:

1.    I have reviewed this report on Form 10-Q of Southern California Gas Company;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and

(d)    Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.    The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

August 4, 2022	/s/ Mia L. DeMontigny
	Mia L. DeMontigny
	Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal executive officer of Sempra Energy (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ J. Walker Martin
	J. Walker Martin
	Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal financial officer of Sempra Energy (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ Trevor I. Mihalik
	Trevor I. Mihalik
	Chief Financial Officer

EX-32.3

Exhibit 32.3

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal executive officer of San Diego Gas & Electric Company (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ Caroline A. Winn
	Caroline A. Winn
	Chief Executive Officer

EX-32.4

Exhibit 32.4

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal financial officer of San Diego Gas & Electric Company (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ Bruce A. Folkmann
	Bruce A. Folkmann
	Chief Financial Officer

EX-32.5

Exhibit 32.5

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal executive officer of Southern California Gas Company (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ Scott D. Drury
	Scott D. Drury
	Chief Executive Officer

EX-32.6

Exhibit 32.6

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350

Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned principal financial officer of Southern California Gas Company (the "Company") certifies that:

(i)the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2022 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and

(ii)the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022	/s/ Mia L. DeMontigny
	Mia L. DeMontigny
	Chief Financial Officer

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COVER - shares	6 Months Ended
	Jun. 30, 2022	Aug. 01, 2022
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA ENERGY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		314,310,331
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company
Document Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8326 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 Fifth 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

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
REVENUES
Natural gas	$ 1,704	$ 1,278	$ 4,024	$ 3,055
Electric	1,189	1,156	2,306	2,224
Energy-related businesses	654	307	1,037	721
Total revenues	3,547	2,741	7,367	6,000
Operating expenses
Operation and maintenance	(1,162)	(1,024)	(2,248)	(2,025)
Aliso Canyon litigation and regulatory matters	(45)	0	(137)	0
Depreciation and amortization	(501)	(463)	(994)	(905)
Franchise fees and other taxes	(150)	(138)	(312)	(291)
Other (expense) income, net	(1)	72	37	107
Interest income	15	15	40	34
Interest expense	(271)	(258)	(514)	(517)
Income before income taxes and equity earnings	364	281	1,029	1,049
Income tax expense	(80)	(139)	(414)	(297)
Equity earnings	375	313	701	631
Net income	659	455	1,316	1,383
Earnings attributable to noncontrolling interests	(88)	(10)	(122)	(43)
Preferred dividends	(11)	(20)	(22)	(41)
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Earnings attributable to common shares	$ 559	$ 424	$ 1,171	$ 1,298
Basic EPS:
Earnings (in dollars per share)	$ 1.78	$ 1.38	$ 3.71	$ 4.27
Weighted-average common shares outstanding (in shares)	314,845	307,800	315,595	304,372
Diluted EPS:
Earnings (in dollars per share)	$ 1.77	$ 1.37	$ 3.70	$ 4.24
Weighted-average common shares outstanding (in shares)	315,867	308,607	316,647	306,284
Natural gas
Operating expenses
Operating expenses	$ (528)	$ (261)	$ (1,330)	$ (610)
Electric fuel and purchased power
Operating expenses
Operating expenses	(251)	(284)	(456)	(516)
Energy-related businesses
Operating expenses
Operating expenses	$ (289)	$ (119)	$ (424)	$ (228)

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 659	$ 455	$ 1,316	$ 1,383
Other comprehensive income (loss):
Foreign currency translation adjustments	2	6	6
Financial instruments	63	(18)	161	89
Pension and other postretirement benefits	3	0	11	14
Total other comprehensive (loss) income	68	(12)	178	103
Comprehensive income	727	443	1,494	1,486
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income, after preferred dividends of subsidiary	726	442	1,493	1,485
Pretax amount
Net income	651	584	1,608	1,637
Other comprehensive income (loss):
Foreign currency translation adjustments	2	5	5
Financial instruments	65	(14)	167	107
Pension and other postretirement benefits	4	1	13	18
Total other comprehensive (loss) income	71	(8)	185	125
Comprehensive income	722	576	1,793	1,762
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income, after preferred dividends of subsidiary	721	575	1,792	1,761
Income tax (expense) benefit
Net income	(80)	(139)	(414)	(297)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0
Financial instruments	(17)	2	(41)	(27)
Pension and other postretirement benefits	(1)	(1)	(2)	(4)
Total other comprehensive (loss) income	(18)	1	(43)	(31)
Comprehensive income	(98)	(138)	(457)	(328)
Preferred dividends of subsidiary	0	0	0	0
Comprehensive income, after preferred dividends of subsidiary	(98)	(138)	(457)	(328)
Net-of-tax amount
Net income	571	445	1,194	1,340
Other comprehensive income (loss):
Foreign currency translation adjustments	2	5	5
Financial instruments	48	(12)	126	80
Pension and other postretirement benefits	3	0	11	14
Total other comprehensive (loss) income	53	(7)	142	94
Comprehensive income	624	438	1,336	1,434
Preferred dividends of subsidiary	(1)	(1)	(1)	(1)
Comprehensive income, after preferred dividends of subsidiary	623	437	1,335	1,433
Noncontrolling interests (after tax)
Net income	88	10	122	43
Other comprehensive income (loss):
Foreign currency translation adjustments	0	1	1
Financial instruments	15	(6)	35	9
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive (loss) income	15	(5)	36	9
Comprehensive income	103	5	158	52
Preferred dividends of subsidiary	0	0	0	0
Comprehensive income, after preferred dividends of subsidiary	$ 103	$ 5	$ 158	$ 52

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CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 1,931	$ 559	[1]
Restricted cash	103	19	[1]
Accounts receivable – trade, net	1,839	2,071	[1]
Accounts receivable – other, net	323	398	[1]
Due from unconsolidated affiliates	646	23	[1]
Income taxes receivable	73	79	[1]
Inventories	377	389	[1]
Prepaid expenses	173	260
Regulatory assets	145	271	[1]
Greenhouse gas allowances	98	97	[1]
Other current assets	194	209	[1]
Total current assets	5,902	4,375	[1]
Other assets:
Restricted cash	59	3	[1]
Due from unconsolidated affiliates	0	637	[1]
Regulatory assets	2,465	2,011	[1]
Insurance receivable for Aliso Canyon costs	344	360	[1]
Greenhouse gas allowances	643	422	[1]
Nuclear decommissioning trusts	863	1,012	[1]
Dedicated assets in support of certain benefit plans	498	567	[1]
Deferred income taxes	138	151	[1]
Right-of-use assets – operating leases	580	594	[1]
Investment in Oncor Holdings	13,301	12,947	[1]
Other investments	1,792	1,525	[1]
Goodwill	1,602	1,602	[1]
Other intangible assets	357	370	[1]
Wildfire fund	317	331	[1]
Other long-term assets	1,319	1,244	[1]
Total other assets	24,278	23,776	[1]
Property, plant and equipment:
Property, plant and equipment	60,855	58,940	[1]
Less accumulated depreciation and amortization	(15,453)	(15,046)	[1]
Property, plant and equipment, net	45,402	43,894	[1]
ASSETS	75,582	72,045	[1]
Current liabilities:
Short-term debt	955	3,471	[1]
Accounts payable – trade	1,604	1,671	[1]
Accounts payable – other	215	178	[1]
Dividends and interest payable	609	563	[1]
Accrued compensation and benefits	334	479	[1]
Regulatory liabilities	307	359	[1]
Current portion of long-term debt and finance leases	303	106	[1]
Reserve for Aliso Canyon costs	2,003	1,980	[1]
Greenhouse gas obligations	98	97	[1]
Other current liabilities	1,122	1,131	[1]
Total current liabilities	7,550	10,035	[1]
Long-term debt and finance leases	24,661	21,068	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	282	287	[1]
Regulatory liabilities	3,295	3,402	[1]
Greenhouse gas obligations	392	225	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	678	687	[1]
Deferred income taxes	4,212	3,477	[1]
Asset retirement obligations	3,467	3,375	[1]
Deferred credits and other	1,992	2,070	[1]
Total deferred credits and other liabilities	14,318	13,523	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,121	11,862	[1]
Retained earnings	13,998	13,548	[1]
Accumulated other comprehensive income (loss)	(167)	(318)	[1]
Total shareholders’ equity	26,841	25,981	[1]
Preferred stock of subsidiary	20	20	[1]
Other noncontrolling interests	2,192	1,418	[1]
Total equity	29,053	27,419	[1]
Total liabilities and equity	75,582	72,045	[1]
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	[1]

[1] Derived from audited financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Jun. 30, 2022	Dec. 31, 2021
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	314,000,000	317,000,000
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,316	$ 1,383
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	994	905
Deferred income taxes and investment tax credits	379	193
Equity earnings	(701)	(631)
Foreign currency transaction losses (gains), net	22	(7)
Share-based compensation expense	32	34
Fixed-price contracts and other derivatives	122	199
Other	101	54
Net change in working capital components	(3)	(63)
Insurance receivable for Aliso Canyon costs	16	31
Distributions from investments	403	532
Changes in other noncurrent assets and liabilities, net	(317)	(375)
Net cash provided by operating activities	2,364	2,255
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(2,361)	(2,424)
Expenditures for investments and acquisitions	(181)	(165)
Purchases of nuclear decommissioning trust assets	(397)	(542)
Proceeds from sales of nuclear decommissioning trust assets	397	542
Advances to unconsolidated affiliates	0	(8)
Distributions from investments	0	4
Other	7	5
Net cash used in investing activities	(2,535)	(2,588)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(711)	(634)
Preferred dividends paid	(22)	(68)
Issuances of common stock	3	5
Repurchases of common stock	(476)	(38)
Issuances of debt (maturities greater than 90 days)	4,818	285
Payments on debt (maturities greater than 90 days) and finance leases	(1,543)	(1,432)
(Decrease) increase in short-term debt, net	(2,011)	1,584
Advances from unconsolidated affiliates	18	20
Proceeds from sale of noncontrolling interests, net	1,732	7
Purchases of noncontrolling interests	0	(10)
Distributions to noncontrolling interests	(106)	0
Contributions from noncontrolling interests	13	0
Other	(30)	(1)
Net cash provided by (used in) financing activities	1,685	(282)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(2)	1
Increase (decrease) in cash, cash equivalents and restricted cash	1,512	(614)
Cash, cash equivalents and restricted cash, January 1	581	985
Cash, cash equivalents and restricted cash, June 30	2,093	371
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	466	488
Income tax payments, net of refunds	233	73
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Increase in Cameron LNG JV investment for guarantee	0	22
Repayment of advances from unconsolidated affiliate in lieu of distribution	32	0
Accrued capital expenditures	476	526
Increase in finance lease obligations for investment in PP&E	22	24
Increase in ARO for investment in PP&E	55	8
Issuance of common stock in exchange for NCI and related AOCI	0	1,373
Conversion of mandatory convertible preferred stock	0	1,693
Preferred stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	11	20
Common stock
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	$ 359	$ 347

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series C Preferred Stock	Series B Preferred Stock	Preferred stock	Preferred stock Preferred Class A	Common stock	Common stock Preferred Class A	Retained earnings	Retained earnings Series C Preferred Stock	Retained earnings Series B Preferred Stock	Accumulated other comprehensive income (loss)	Sempra Energy shareholders' equity	Sempra Energy shareholders' equity Series C Preferred Stock	Sempra Energy shareholders' equity Series B Preferred Stock	Non- controlling interests
Beginning Balance at Dec. 31, 2020	$ 24,934				$ 3,147		$ 7,053		$ 13,673			$ (500)	$ 23,373			$ 1,561
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,383								1,340				1,340			43
Total other comprehensive (loss) income	103											94	94			9
Share-based compensation expense	34						34						34
Dividends declared:
Preferred dividends			$ (22)	$ (19)						$ (22)	$ (19)			$ (22)	$ (19)
Common stock dividends declared	(680)								(680)				(680)
Preferred dividends of subsidiary	(1)								(1)				(1)
Conversion of stock	0					$ (1,693)		$ 1,693
Issuances of common stock	5						5						5
Repurchases of common stock	(38)						(38)						(38)
Noncontrolling interest activities:
Purchases	(12)						1,399					(38)	1,361			(1,373)
Sale	5						4						4			1
Ending balance at Jun. 30, 2021	25,692				1,454		10,150		14,291			(444)	25,451			241
Beginning Balance at Mar. 31, 2021	25,608				1,454		8,730		14,214			(399)	23,999			1,609
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	455								445				445			10
Total other comprehensive (loss) income	(12)											(7)	(7)			(5)
Share-based compensation expense	17						17						17
Dividends declared:
Preferred dividends			(11)	$ (9)						(11)	$ (9)			(11)	$ (9)
Common stock dividends declared	(347)								(347)				(347)
Preferred dividends of subsidiary	(1)								(1)				(1)
Issuances of common stock	5						5						5
Repurchases of common stock	(1)						(1)						(1)
Noncontrolling interest activities:
Purchases	(12)						1,399					(38)	1,361			(1,373)
Ending balance at Jun. 30, 2021	25,692				1,454		10,150		14,291			(444)	25,451			241
Beginning Balance at Dec. 31, 2021	27,419	[1]			889		11,862		13,548			(318)	25,981			1,438
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,316								1,194				1,194			122
Total other comprehensive (loss) income	178											142	142			36
Share-based compensation expense	32						32						32
Dividends declared:
Preferred dividends			(22)							(22)				(22)
Common stock dividends declared	(721)								(721)				(721)
Preferred dividends of subsidiary	(1)								(1)				(1)
Issuances of common stock	3						3						3
Repurchases of common stock	(476)						(476)						(476)
Noncontrolling interest activities:
Contributions	13															13
Distributions	(106)															(106)
Sale	1,418						700					9	709			709
Ending balance at Jun. 30, 2022	29,053				889		12,121		13,998			(167)	26,841			2,212
Beginning Balance at Mar. 31, 2022	27,560				889		11,656		13,798			(229)	26,114			1,446
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	659								571				571			88
Total other comprehensive (loss) income	68											53	53			15
Share-based compensation expense	15						15						15
Dividends declared:
Preferred dividends			$ (11)							$ (11)				$ (11)
Common stock dividends declared	(359)								(359)				(359)
Preferred dividends of subsidiary	(1)								(1)				(1)
Repurchases of common stock	(250)						(250)						(250)
Noncontrolling interest activities:
Contributions	7															7
Distributions	(53)															(53)
Sale	1,418						700					9	709			709
Ending balance at Jun. 30, 2022	$ 29,053				$ 889		$ 12,121		$ 13,998			$ (167)	$ 26,841			$ 2,212

[1] Derived from audited financial statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Dividends declared per share of common stock (in dollars per share)	$ 1.14	$ 1.10	$ 2.29	$ 2.20
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	12.19	$ 24.38	24.38
Series B Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)		$ 1.69		$ 3.38

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CONDENSED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
REVENUES
Electric	$ 1,189	$ 1,156	$ 2,306	$ 2,224
Natural gas	1,704	1,278	4,024	3,055
Operating expenses
Other (expense) income, net	(1)	72	37	107
Interest income	15	15	40	34
Interest expense	(271)	(258)	(514)	(517)
Income before income taxes and equity earnings	364	281	1,029	1,049
Income tax expense	(80)	(139)	(414)	(297)
Earnings attributable to common shares	559	424	1,171	1,298
San Diego Gas and Electric Company
REVENUES
Electric	1,192	1,158	2,312	2,227
Natural gas	207	160	532	428
Operating revenues	1,399	1,318	2,844	2,655
Operating expenses
Cost of electric fuel and purchased power	269	304	490	545
Cost of natural gas	69	40	195	122
Operation and maintenance	420	373	817	763
Depreciation and amortization	244	220	483	433
Franchise fees and other taxes	88	83	180	171
Total operating expenses	1,090	1,020	2,165	2,034
Operating income	309	298	679	621
Other (expense) income, net	22	22	56	57
Interest income	1	0	1	1
Interest expense	(114)	(101)	(220)	(203)
Income before income taxes and equity earnings	218	219	516	476
Income tax expense	(42)	(33)	(106)	(78)
Earnings attributable to common shares	$ 176	$ 186	$ 410	$ 398

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CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 659	$ 455	$ 1,316	$ 1,383
Comprehensive income	726	442	1,493	1,485
Pretax amount
Net income	651	584	1,608	1,637
Comprehensive income	721	575	1,792	1,761
Income tax (expense) benefit
Net income	(80)	(139)	(414)	(297)
Comprehensive income	(98)	(138)	(457)	(328)
Net-of-tax amount
Net income	571	445	1,194	1,340
Comprehensive income	623	437	1,335	1,433
San Diego Gas and Electric Company
Net income			410	398
San Diego Gas and Electric Company | Pretax amount
Net income	218	219	516	476
Comprehensive income	218	219	516	476
San Diego Gas and Electric Company | Income tax (expense) benefit
Net income	(42)	(33)	(106)	(78)
Comprehensive income	(42)	(33)	(106)	(78)
San Diego Gas and Electric Company | Net-of-tax amount
Net income	176	186	410	398
Comprehensive income	$ 176	$ 186	$ 410	$ 398

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CONDENSED BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 1,931	$ 559	[1]
Accounts receivable – trade, net	1,839	2,071	[1]
Accounts receivable – other, net	323	398	[1]
Income taxes receivable	73	79	[1]
Inventories	377	389	[1]
Prepaid expenses	173	260
Regulatory assets	145	271	[1]
Greenhouse gas allowances	98	97	[1]
Other current assets	194	209	[1]
Total current assets	5,902	4,375	[1]
Other assets:
Regulatory assets	2,465	2,011	[1]
Greenhouse gas allowances	643	422	[1]
Nuclear decommissioning trusts	863	1,012	[1]
Right-of-use assets – operating leases	580	594	[1]
Wildfire fund	317	331	[1]
Other long-term assets	1,319	1,244	[1]
Total other assets	24,278	23,776	[1]
Property, plant and equipment:
Property, plant and equipment	60,855	58,940	[1]
Less accumulated depreciation and amortization	(15,453)	(15,046)	[1]
Property, plant and equipment, net	45,402	43,894	[1]
ASSETS	75,582	72,045	[1]
Current liabilities:
Short-term debt	955	3,471	[1]
Accrued compensation and benefits	334	479	[1]
Regulatory liabilities	307	359	[1]
Current portion of long-term debt and finance leases	303	106	[1]
Greenhouse gas obligations	98	97	[1]
Other current liabilities	1,122	1,131	[1]
Total current liabilities	7,550	10,035	[1]
Long-term debt and finance leases	24,661	21,068	[1]
Deferred credits and other liabilities:
Regulatory liabilities	3,295	3,402	[1]
Greenhouse gas obligations	392	225	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	678	687	[1]
Deferred income taxes	4,212	3,477	[1]
Asset retirement obligations	3,467	3,375	[1]
Deferred credits and other	1,992	2,070	[1]
Total deferred credits and other liabilities	14,318	13,523	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,121	11,862	[1]
Retained earnings	13,998	13,548	[1]
Accumulated other comprehensive income (loss)	(167)	(318)	[1]
Total shareholders’ equity	26,841	25,981	[1]
Total liabilities and equity	75,582	72,045	[1]
San Diego Gas and Electric Company
Current assets:
Cash and cash equivalents	533	25	[1]
Accounts receivable – trade, net	685	715	[1]
Accounts receivable – other, net	72	78	[1]
Income taxes receivable	11	9	[1]
Inventories	124	123	[1]
Prepaid expenses	115	174	[1]
Regulatory assets	134	231	[1]
Greenhouse gas allowances	13	13	[1]
Other current assets	65	63	[1]
Total current assets	1,752	1,431	[1]
Other assets:
Regulatory assets	947	786	[1]
Greenhouse gas allowances	127	111	[1]
Nuclear decommissioning trusts	863	1,012	[1]
Right-of-use assets – operating leases	198	185	[1]
Wildfire fund	317	331	[1]
Other long-term assets	130	154	[1]
Total other assets	2,582	2,579	[1]
Property, plant and equipment:
Property, plant and equipment	27,201	26,456	[1]
Less accumulated depreciation and amortization	(6,460)	(6,408)	[1]
Property, plant and equipment, net	20,741	20,048	[1]
ASSETS	25,075	24,058	[1]
Current liabilities:
Short-term debt	0	776	[1]
Accounts payable	635	588	[1]
Due to unconsolidated affiliates	68	97	[1]
Interest payable	61	50	[1]
Accrued compensation and benefits	87	148	[1]
Regulatory liabilities	13	14	[1]
Current portion of long-term debt and finance leases	35	49	[1]
Customer deposits	27	30	[1]
Greenhouse gas obligations	13	13	[1]
Asset retirement obligations	94	86	[1]
Other current liabilities	281	260	[1]
Total current liabilities	1,314	2,111	[1]
Long-term debt and finance leases	8,958	7,581	[1]
Deferred credits and other liabilities:
Regulatory liabilities	2,213	2,302	[1]
Greenhouse gas obligations	57	31	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	24	25	[1]
Deferred income taxes	2,368	2,275	[1]
Asset retirement obligations	791	804	[1]
Deferred credits and other	691	680	[1]
Total deferred credits and other liabilities	6,144	6,117	[1]
Commitments and contingencies			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,660	1,660	[1]
Retained earnings	7,009	6,599	[1]
Accumulated other comprehensive income (loss)	(10)	(10)	[1]
Total shareholders’ equity	8,659	8,249	[1]
Total liabilities and equity	$ 25,075	$ 24,058	[1]

[1] Derived from audited financial statements.

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CONDENSED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Jun. 30, 2022	Dec. 31, 2021
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	314,000,000	317,000,000
San Diego Gas and Electric Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	117,000,000	117,000,000

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CONDENSED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,316	$ 1,383
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	994	905
Deferred income taxes and investment tax credits	379	193
Other	101	54
Net change in working capital components	(3)	(63)
Changes in other noncurrent assets and liabilities, net	(317)	(375)
Net cash provided by operating activities	2,364	2,255
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(2,361)	(2,424)
Purchases of nuclear decommissioning trust assets	(397)	(542)
Proceeds from sales of nuclear decommissioning trust assets	397	542
Other	7	5
Net cash used in investing activities	(2,535)	(2,588)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	4,818	285
Payments on debt (maturities greater than 90 days) and finance leases	(1,543)	(1,432)
(Decrease) increase in short-term debt, net	(2,011)	1,584
Net cash provided by (used in) financing activities	1,685	(282)
Increase (decrease) in cash, cash equivalents and restricted cash	1,512	(614)
Cash, cash equivalents and restricted cash, January 1	581	985
Cash, cash equivalents and restricted cash, June 30	2,093	371
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	466	488
Income tax payments, net of refunds	233	73
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	476	526
Increase in finance lease obligations for investment in PP&E	22	24
San Diego Gas and Electric Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	410	398
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	483	433
Deferred income taxes and investment tax credits	41	41
Other	19	(13)
Net change in working capital components	165	(136)
Changes in other noncurrent assets and liabilities, net	(105)	(113)
Net cash provided by operating activities	1,013	610
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,090)	(1,072)
Purchases of nuclear decommissioning trust assets	(397)	(542)
Proceeds from sales of nuclear decommissioning trust assets	397	542
Other	8	7
Net cash used in investing activities	(1,082)	(1,065)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of debt (maturities greater than 90 days)	1,395	0
Payments on debt (maturities greater than 90 days) and finance leases	(408)	(231)
(Decrease) increase in short-term debt, net	(401)	437
Debt issuance costs	(9)	0
Net cash provided by (used in) financing activities	577	206
Increase (decrease) in cash, cash equivalents and restricted cash	508	(249)
Cash, cash equivalents and restricted cash, January 1	25	262
Cash, cash equivalents and restricted cash, June 30	533	13
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	206	201
Income tax payments, net of refunds	68	58
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	186	192
Increase in ARO for investment in PP&E	1	18
Increase in finance lease obligations for investment in PP&E	$ 9	$ 13

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CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E - USD ($) $ in Millions	Total		Common stock	Retained earnings	Accumulated other comprehensive income (loss)	Sempra Energy shareholders' equity	San Diego Gas and Electric Company	San Diego Gas and Electric Company Common stock	San Diego Gas and Electric Company Retained earnings	San Diego Gas and Electric Company Accumulated other comprehensive income (loss)	San Diego Gas and Electric Company Sempra Energy shareholders' equity
Beginning Balance at Dec. 31, 2020	$ 24,934		$ 7,053	$ 13,673	$ (500)	$ 23,373		$ 1,660	$ 6,080	$ (10)	$ 7,730
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,383			1,340		1,340	$ 398		398		398
Ending balance at Jun. 30, 2021	25,692		10,150	14,291	(444)	25,451		1,660	6,478	(10)	8,128
Beginning Balance at Mar. 31, 2021	25,608		8,730	14,214	(399)	23,999		1,660	6,292	(10)	7,942
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	455			445		445			186		186
Ending balance at Jun. 30, 2021	25,692		10,150	14,291	(444)	25,451		1,660	6,478	(10)	8,128
Beginning Balance at Dec. 31, 2021	27,419	[1]	11,862	13,548	(318)	25,981		1,660	6,599	(10)	8,249
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,316			1,194		1,194	$ 410		410		410
Ending balance at Jun. 30, 2022	29,053		12,121	13,998	(167)	26,841		1,660	7,009	(10)	8,659
Beginning Balance at Mar. 31, 2022	27,560		11,656	13,798	(229)	26,114		1,660	6,833	(10)	8,483
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	659			571		571			176		176
Ending balance at Jun. 30, 2022	$ 29,053		$ 12,121	$ 13,998	$ (167)	$ 26,841		$ 1,660	$ 7,009	$ (10)	$ 8,659

[1] Derived from audited financial statements.

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CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY - SDG&E (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Dividends declared per share of common stock (in dollars per share)	$ 1.14	$ 1.10	$ 2.29	$ 2.20
Southern California Gas Company
Dividends declared per share of preferred stock (in dollars per share)	0.37	0.37	0.75	0.75
Dividends declared per share of common stock (in dollars per share)		0.27		0.82
Series B Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)		1.69		3.38
Series C Preferred Stock
Dividends declared per share of preferred stock (in dollars per share)	$ 12.19	$ 12.19	$ 24.38	$ 24.38

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CONDENSED STATEMENTS OF OPERATIONS - SoCalGas - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating expenses
Aliso Canyon litigation and regulatory matters	$ 45	$ 0	$ 137	$ 0
Other (expense) income, net	(1)	72	37	107
Interest income	15	15	40	34
Interest expense	(271)	(258)	(514)	(517)
Income before income taxes	523	466	1,331	1,369
Income tax expense	(80)	(139)	(414)	(297)
Net income	659	455	1,316	1,383
Preferred dividends	(11)	(20)	(22)	(41)
Earnings attributable to common shares	559	424	1,171	1,298
Southern California Gas Company
REVENUES
Operating revenues	1,501	1,124	3,494	2,632
Operating expenses
Cost of natural gas	459	223	1,136	496
Operation and maintenance	605	525	1,156	1,028
Aliso Canyon litigation and regulatory matters	45	0	137	0
Depreciation and amortization	188	180	375	353
Franchise fees and other taxes	57	51	119	109
Total operating expenses	1,354	979	2,923	1,986
Operating income	147	145	571	646
Other (expense) income, net	4	(2)	38	37
Interest income	1	0	1	0
Interest expense	(45)	(40)	(85)	(79)
Income before income taxes	107	103	525	604
Income tax expense	(19)	(8)	(103)	(102)
Net income	88	95	422	502
Preferred dividends	(1)	(1)	(1)	(1)
Earnings attributable to common shares	$ 87	$ 94	$ 421	$ 501

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CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SoCalGas - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 659	$ 455	$ 1,316	$ 1,383
Other comprehensive income (loss):
Financial instruments	63	(18)	161	89
Pension and other postretirement benefits	3	0	11	14
Total other comprehensive (loss) income	68	(12)	178	103
Comprehensive income	726	442	1,493	1,485
Pretax amount
Net income	651	584	1,608	1,637
Other comprehensive income (loss):
Financial instruments	65	(14)	167	107
Pension and other postretirement benefits	4	1	13	18
Total other comprehensive (loss) income	71	(8)	185	125
Comprehensive income	721	575	1,792	1,761
Income tax (expense) benefit
Net income	(80)	(139)	(414)	(297)
Other comprehensive income (loss):
Financial instruments	(17)	2	(41)	(27)
Pension and other postretirement benefits	(1)	(1)	(2)	(4)
Total other comprehensive (loss) income	(18)	1	(43)	(31)
Comprehensive income	(98)	(138)	(457)	(328)
Net-of-tax amount
Net income	571	445	1,194	1,340
Other comprehensive income (loss):
Financial instruments	48	(12)	126	80
Pension and other postretirement benefits	3	0	11	14
Total other comprehensive (loss) income	53	(7)	142	94
Comprehensive income	623	437	1,335	1,433
Southern California Gas Company
Net income	88	95	422	502
Other comprehensive income (loss):
Total other comprehensive (loss) income	1	1	2	1
Southern California Gas Company | Pretax amount
Net income	107	103	525	604
Other comprehensive income (loss):
Financial instruments	1		1
Pension and other postretirement benefits		1	1	1
Total other comprehensive (loss) income	1	1	2	1
Comprehensive income	108	104	527	605
Southern California Gas Company | Income tax (expense) benefit
Net income	(19)	(8)	(103)	(102)
Other comprehensive income (loss):
Financial instruments	0		0
Pension and other postretirement benefits		0	0	0
Total other comprehensive (loss) income	0	0	0	0
Comprehensive income	(19)	(8)	(103)	(102)
Southern California Gas Company | Net-of-tax amount
Net income	88	95	422	502
Other comprehensive income (loss):
Financial instruments	1		1
Pension and other postretirement benefits		1	1	1
Total other comprehensive (loss) income	1	1	2	1
Comprehensive income	$ 89	$ 96	$ 424	$ 503

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CONDENSED BALANCE SHEETS - SoCalGas - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 1,931	$ 559	[1]
Accounts receivable – trade, net	1,839	2,071	[1]
Accounts receivable – other, net	323	398	[1]
Due from unconsolidated affiliates	646	23	[1]
Income taxes receivable	73	79	[1]
Inventories	377	389	[1]
Regulatory assets	145	271	[1]
Greenhouse gas allowances	98	97	[1]
Other current assets	194	209	[1]
Total current assets	5,902	4,375	[1]
Other assets:
Regulatory assets	2,465	2,011	[1]
Insurance receivable for Aliso Canyon costs	344	360	[1]
Greenhouse gas allowances	643	422	[1]
Right-of-use assets – operating leases	580	594	[1]
Other long-term assets	1,319	1,244	[1]
Total other assets	24,278	23,776	[1]
Property, plant and equipment:
Property, plant and equipment	60,855	58,940	[1]
Less accumulated depreciation and amortization	(15,453)	(15,046)	[1]
Property, plant and equipment, net	45,402	43,894	[1]
ASSETS	75,582	72,045	[1]
Current liabilities:
Short-term debt	955	3,471	[1]
Accounts payable – trade	1,604	1,671	[1]
Accounts payable – other	215	178	[1]
Accrued compensation and benefits	334	479	[1]
Regulatory liabilities	307	359	[1]
Current portion of long-term debt and finance leases	303	106	[1]
Reserve for Aliso Canyon costs	2,003	1,980	[1]
Greenhouse gas obligations	98	97	[1]
Other current liabilities	1,122	1,131	[1]
Total current liabilities	7,550	10,035	[1]
Long-term debt and finance leases	24,661	21,068	[1]
Deferred credits and other liabilities:
Regulatory liabilities	3,295	3,402	[1]
Greenhouse gas obligations	392	225	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	678	687	[1]
Deferred income taxes	4,212	3,477	[1]
Asset retirement obligations	3,467	3,375	[1]
Deferred credits and other	1,992	2,070	[1]
Total deferred credits and other liabilities	14,318	13,523	[1]
Commitments and contingencies			[1]
Equity:
Common stock	12,121	11,862	[1]
Retained earnings	13,998	13,548	[1]
Accumulated other comprehensive income (loss)	(167)	(318)	[1]
Total shareholders’ equity	26,841	25,981	[1]
Total liabilities and equity	75,582	72,045	[1]
Southern California Gas Company
Current assets:
Cash and cash equivalents	416	37	[1]
Accounts receivable – trade, net	722	1,084	[1]
Accounts receivable – other, net	48	58	[1]
Due from unconsolidated affiliates	31	49	[1]
Income taxes receivable	23	23	[1]
Inventories	169	172	[1]
Regulatory assets	11	40	[1]
Greenhouse gas allowances	76	75	[1]
Other current assets	32	61	[1]
Total current assets	1,528	1,599	[1]
Other assets:
Regulatory assets	1,441	1,148	[1]
Insurance receivable for Aliso Canyon costs	344	360	[1]
Greenhouse gas allowances	488	290	[1]
Right-of-use assets – operating leases	49	57	[1]
Other long-term assets	616	627	[1]
Total other assets	2,938	2,482	[1]
Property, plant and equipment:
Property, plant and equipment	23,975	23,104	[1]
Less accumulated depreciation and amortization	(7,087)	(6,861)	[1]
Property, plant and equipment, net	16,888	16,243	[1]
ASSETS	21,354	20,324	[1]
Current liabilities:
Short-term debt	0	385	[2]
Accounts payable – trade	647	775	[2]
Accounts payable – other	152	142	[2]
Due to unconsolidated affiliates	36	36	[2]
Accrued compensation and benefits	159	202	[2]
Regulatory liabilities	294	345	[2]
Current portion of long-term debt and finance leases	13	11	[2]
Customer deposits	15	13	[2]
Reserve for Aliso Canyon costs	2,003	1,980	[2]
Greenhouse gas obligations	76	75	[2]
Asset retirement obligations	76	77	[2]
Other current liabilities	230	271	[2]
Total current liabilities	3,701	4,312	[2]
Long-term debt and finance leases	5,471	4,773	[2]
Deferred credits and other liabilities:
Regulatory liabilities	1,082	1,100	[2]
Greenhouse gas obligations	303	174	[2]
Pension and other postretirement benefit plan obligations, net of plan assets	545	551	[2]
Deferred income taxes	1,212	1,039	[2]
Asset retirement obligations	2,609	2,505	[2]
Deferred credits and other	416	428	[2]
Total deferred credits and other liabilities	6,167	5,797	[2]
Commitments and contingencies			[2]
Equity:
Preferred stock	22	22	[2]
Common stock	1,816	1,666	[2]
Retained earnings	4,206	3,785	[2]
Accumulated other comprehensive income (loss)	(29)	(31)	[2]
Total shareholders’ equity	6,015	5,442	[2]
Total liabilities and equity	$ 21,354	$ 20,324	[2]

[1] Derived from audited financial statements.

[2] Derived from audited financial statements.

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CONDENSED BALANCE SHEETS - SoCalGas (Parentheticals) - shares	Jun. 30, 2022	Dec. 31, 2021
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	314,000,000	317,000,000
Southern California Gas Company
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	1,000,000	1,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,000,000	91,000,000

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CONDENSED STATEMENTS OF CASH FLOWS - SoCalGas - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,316	$ 1,383
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	994	905
Deferred income taxes and investment tax credits	379	193
Other	101	54
Net change in working capital components	(3)	(63)
Insurance receivable for Aliso Canyon costs	16	31
Changes in other noncurrent assets and liabilities, net	(317)	(375)
Net cash provided by operating activities	2,364	2,255
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(2,361)	(2,424)
Net cash used in investing activities	(2,535)	(2,588)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(22)	(68)
Common dividends paid	(711)	(634)
Issuances of debt (maturities greater than 90 days)	4,818	285
(Decrease) increase in short-term debt, net	(2,011)	1,584
Net cash provided by (used in) financing activities	1,685	(282)
Increase (decrease) in cash, cash equivalents and restricted cash	1,512	(614)
Cash, cash equivalents and restricted cash, January 1	581	985
Cash, cash equivalents and restricted cash, June 30	2,093	371
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	466	488
Income tax payments, net of refunds	233	73
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	476	526
Increase in ARO for investment in PP&E	55	8
Increase in finance lease obligations for investment in PP&E	22	24
Southern California Gas Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	422	502
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	375	353
Deferred income taxes and investment tax credits	103	18
Other	36	42
Net change in working capital components	225	297
Insurance receivable for Aliso Canyon costs	16	31
Changes in other noncurrent assets and liabilities, net	(316)	(280)
Net cash provided by operating activities	861	963
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(931)	(936)
Net cash used in investing activities	(931)	(936)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)	(1)
Common dividends paid	0	(50)
Equity contribution from Sempra Energy	150	0
Issuances of debt (maturities greater than 90 days)	697	0
Payments on finance leases	(6)	(6)
(Decrease) increase in short-term debt, net	(385)	30
Debt issuance costs	(6)	0
Net cash provided by (used in) financing activities	449	(27)
Increase (decrease) in cash, cash equivalents and restricted cash	379	0
Cash, cash equivalents and restricted cash, January 1	37	4
Cash, cash equivalents and restricted cash, June 30	416	4
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	75	76
Income tax payments, net of refunds	0	82
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	199	156
Increase in ARO for investment in PP&E	54	(10)
Increase in finance lease obligations for investment in PP&E	13	11
Dividends declared but not paid	$ 0	$ 25

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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	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, 2020	$ 24,934		$ 3,147	$ 7,053	$ 13,673	$ (500)	$ 5,144	$ 22	$ 866	$ 4,287	$ (31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,383				1,340		502			502
Other comprehensive (loss) income	103					94	1				1
Dividends declared:
Preferred dividends							(1)			(1)
Common stock dividends declared	(680)				(680)		(75)			(75)
Ending balance at Jun. 30, 2021	25,692		1,454	10,150	14,291	(444)	5,571	22	866	4,713	(30)
Beginning Balance at Mar. 31, 2021	25,608		1,454	8,730	14,214	(399)	5,501	22	866	4,644	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	455				445		95			95
Other comprehensive (loss) income	(12)					(7)	1				1
Dividends declared:
Preferred dividends							(1)			(1)
Common stock dividends declared	(347)				(347)		(25)			(25)
Ending balance at Jun. 30, 2021	25,692		1,454	10,150	14,291	(444)	5,571	22	866	4,713	(30)
Beginning Balance at Dec. 31, 2021	27,419	[1]	889	11,862	13,548	(318)	5,442	22	1,666	3,785	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,316				1,194		422			422
Other comprehensive (loss) income	178					142	2				2
Dividends declared:
Preferred dividends							(1)			(1)
Common stock dividends declared	(721)				(721)
Equity contribution from Sempra Energy							150		150
Ending balance at Jun. 30, 2022	29,053		889	12,121	13,998	(167)	6,015	22	1,816	4,206	(29)
Beginning Balance at Mar. 31, 2022	27,560		889	11,656	13,798	(229)	5,777	22	1,666	4,119	(30)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	659				571		88			88
Other comprehensive (loss) income	68					53	1				1
Dividends declared:
Preferred dividends							(1)			(1)
Common stock dividends declared	(359)				(359)
Equity contribution from Sempra Energy							150		150
Ending balance at Jun. 30, 2022	$ 29,053		$ 889	$ 12,121	$ 13,998	$ (167)	$ 6,015	$ 22	$ 1,816	$ 4,206	$ (29)

[1] Derived from audited financial statements.

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CONDENSED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY - SoCalGas (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Dividends declared per share of common stock (in dollars per share)	$ 1.14	$ 1.10	$ 2.29	$ 2.20
Southern California Gas Company
Dividends declared per share of preferred stock (in dollars per share)	$ 0.37	0.37	$ 0.75	0.75
Dividends declared per share of common stock (in dollars per share)		$ 0.27		$ 0.82

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

GENERAL INFORMATION AND OTHER FINANCIAL DATA

GENERAL INFORMATION AND OTHER FINANCIAL DATA

PRINCIPLES OF CONSOLIDATION

Sempra

Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, which resulted in a change to our reportable segments. Historical segment disclosures have been restated to conform with the current presentation of our four separate reportable segments, which we discuss in Note 12. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name.

SDG&E

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

SoCalGas

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

BASIS OF PRESENTATION

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

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2022 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, 2021 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2021 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC.

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

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

Regulated Operations

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

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

Our Sempra Infrastructure segment includes the operating companies of our subsidiary, IEnova, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

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

Restricted cash includes:

▪for Sempra Infrastructure, funds fully drawn against Gazprom’s letters of credit, including draws associated with its LNG storage and regasification agreement that we discuss in Note 11, and funds denominated in Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects

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

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

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2022		December 31, 2021
Cash and cash equivalents	$	1,931	$	559
Restricted cash, current	103		19
Restricted cash, noncurrent	59		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	2,093	$	581

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 6.

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

In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and applied the amounts directly to eligible customer accounts to reduce past due balances. In June 2022, AB 205 was approved establishing, among other things, the 2022 California Arrearage Payment Program. SDG&E and SoCalGas expect to apply for funding from this program on behalf of their residential customers with past due balances and, if approved, receive such funding in the first quarter of 2023.

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

RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2022		2021
Sempra:
Allowances for credit losses at January 1	$	136	$	138
Provisions for expected credit losses	77		66
Write-offs	(36)		(12)
Allowances for credit losses at June 30	$	177	$	192
SDG&E:
Allowances for credit losses at January 1	$	66	$	69
Provisions for expected credit losses	37		13
Write-offs	(18)		(7)
Allowances for credit losses at June 30	$	85	$	75
SoCalGas:
Allowances for credit losses at January 1	$	69	$	68
Provisions for expected credit losses	37		52
Write-offs	(18)		(5)
Allowances for credit losses at June 30	$	88	$	115

Allowances for credit losses related to accounts receivable are included in the Condensed Consolidated Balance Sheets as follows:

ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2022		2021
Sempra:
Accounts receivable – trade, net	$	142	$	94
Accounts receivable – other, net	33		39
Other long-term assets	2		3
Total allowances for credit losses	$	177	$	136
SDG&E:
Accounts receivable – trade, net	$	62	$	42
Accounts receivable – other, net	22		22
Other long-term assets	1		2
Total allowances for credit losses	$	85	$	66
SoCalGas:
Accounts receivable – trade, net	$	76	$	51
Accounts receivable – other, net	11		17
Other long-term assets	1		1
Total allowances for credit losses	$	88	$	69

As we discuss below in “Transactions with Affiliates,” we have loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on amounts due from unconsolidated affiliates, if necessary, based on credit quality indicators such as external credit ratings, published default rate studies, the maturity date of the instrument and past delinquencies. However, we do not record allowances for expected credit losses related to accrued interest receivable on loans due from unconsolidated affiliates because we write off such amounts, if any, through a reversal of interest income in the period we determine such amounts are uncollectible. In the absence of external credit ratings, we may utilize an internally developed credit rating based on our analysis of a counterparty’s financial statements to determine our expected credit losses. At December 31, 2021, $1 million of expected credit losses are included in noncurrent Due From Unconsolidated Affiliates on Sempra’s Condensed Consolidated Balance Sheet.

As we discuss below in “Note Receivable,” we have an interest-bearing promissory note due from KKR. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on this note receivable, including compounded interest and unamortized transaction costs, based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At June 30, 2022 and December 31, 2021, $7 million and $8 million, respectively, of expected credit losses are included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheets.

As we discuss below in Note 6, 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 June 30, 2022 and December 31, 2021, $6 million and $7 million, respectively, of expected credit losses are included in Deferred Credits and Other on Sempra’s Condensed Consolidated Balance Sheets.

INVENTORIES

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Natural gas	$	138	$	164	$	—	$	—	$	102	$	114
LNG	31		27		—		—		—		—
Materials and supplies	208		198		124		123		67		58
Total	$	377	$	389	$	124	$	123	$	169	$	172

NOTE RECEIVABLE

In October 2021, Sempra loaned $300 million to KKR 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. At June 30, 2022 and December 31, 2021, Other Long-Term Assets includes $308 million and $297 million, respectively, of outstanding principal, compounded interest and unamortized transaction costs, net of allowance for credit losses, and at December 31, 2021, Other Current Assets includes $3 million of interest receivable on Sempra’s Condensed Consolidated Balance Sheets.

CAPITALIZED FINANCING COSTS

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

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

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra	$	60	$	55	$	117	$	114
SDG&E	26		28		54		58
SoCalGas	17		15		35		31

VARIABLE INTEREST ENTITIES

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

▪the purpose and design of the VIE;

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

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

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

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

SDG&E

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

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

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

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at June 30, 2022 and December 31, 2021. 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 $1,206 million and $1,217 million at June 30, 2022 and December 31, 2021, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Sempra Texas Utilities

Oncor Holdings is a VIE. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $13,301 million at June 30, 2022 and $12,947 million at December 31, 2021.

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 $723 million at June 30, 2022 and $514 million at December 31, 2021. 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 6.

CFIN

As we discuss in Note 6, 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 9). 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 development activities related to the construction of the liquefaction facility, which we consider to be the most significant activities of ECA LNG Phase 1 during the construction phase of its natural gas liquefaction export project. As a result, we consolidate ECA LNG Phase 1. Sempra consolidated $767 million and $632 million of assets at June 30, 2022 and December 31, 2021, respectively, consisting primarily of PP&E, net, and Accounts Receivable – Other attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $532 million and $455 million of liabilities at June 30, 2022 and December 31, 2021, respectively, consisting primarily of long-term debt, short-term debt and accounts payable attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 7, Sempra and TotalEnergies SE have provided guarantees for the loan facility supporting construction of the liquefaction facility based on their respective proportionate ownership interest in ECA LNG Phase 1.

PENSION AND OTHER POSTRETIREMENT BENEFITS

Net Periodic Benefit Cost

The following three 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 (Expense) Income, Net, table below.

NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	42	$	36	$	6	$	5
Interest cost	29		28		7		7
Expected return on assets	(45)		(43)		(16)		(15)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	5		11		(3)		(2)
Net periodic benefit cost (credit)	33		34		(6)		(5)
Regulatory adjustments	24		22		6		5
Total expense recognized	$	57	$	56	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	83	$	73	$	13	$	11
Interest cost	59		56		14		14
Expected return on assets	(91)		(86)		(32)		(30)
Amortization of:
Prior service cost (credit)	5		5		(1)		(1)
Actuarial loss (gain)	11		22		(7)		(4)
Settlement charges	—		7		—		—
Net periodic benefit cost (credit)	67		77		(13)		(10)
Regulatory adjustments	(3)		(7)		13		10
Total expense recognized	$	64	$	70	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	10	$	9	$	1	$	1
Interest cost	6		6		2		2
Expected return on assets	(11)		(13)		(3)		(3)
Amortization of:
Actuarial loss (gain)	1		1		—		(1)
Net periodic benefit cost (credit)	6		3		—		(1)
Regulatory adjustments	7		11		—		1
Total expense recognized	$	13	$	14	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	20	$	17	$	3	$	2
Interest cost	13		12		3		3
Expected return on assets	(22)		(25)		(5)		(5)
Amortization of:
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	12		5		—		(1)
Regulatory adjustments	2		9		—		1
Total expense recognized	$	14	$	14	$	—	$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	28	$	25	$	5	$	4
Interest cost	21		20		6		6
Expected return on assets	(33)		(30)		(14)		(12)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	4		10		(3)		(2)
Net periodic benefit cost (credit)	22		27		(6)		(4)
Regulatory adjustments	17		11		6		4
Total expense recognized	$	39	$	38	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	56	$	50	$	10	$	8
Interest cost	41		40		11		11
Expected return on assets	(64)		(58)		(27)		(24)
Amortization of:
Prior service cost (credit)	4		4		(1)		(1)
Actuarial loss (gain)	8		19		(6)		(3)
Net periodic benefit cost (credit)	45		55		(13)		(9)
Regulatory adjustments	(5)		(16)		13		9
Total expense recognized	$	40	$	39	$	—	$	—

RABBI TRUST

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 $498 million and $567 million at June 30, 2022 and December 31, 2021, respectively.

SEMPRA EARNINGS PER COMMON SHARE

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

EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Numerator:
Earnings attributable to common shares	$	559	$	424	$	1,171	$	1,298
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	314,845		307,800		315,595		304,372
Dilutive effect of stock options and RSUs(2)	1,022		807		1,052		846
Dilutive effect of mandatory convertible preferred stock	—		—		—		1,066
Weighted-average common shares outstanding for diluted EPS	315,867		308,607		316,647		306,284
EPS:
Basic	$	1.78	$	1.38	$	3.71	$	4.27
Diluted	$	1.77	$	1.37	$	3.70	$	4.24

(1)    Includes 399 and 447 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2022 and 2021, respectively, and 403 and 454 of such RSUs for the six months ended June 30, 2022 and 2021, respectively. These fully vested RSUs are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

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

The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS for the three months and six months ended June 30, 2022 excludes 8,899 and 173,064 potentially dilutive shares, respectively, and the computation of diluted EPS for the three months and six months ended June 30, 2021 excludes 145,247 and 287,061 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future.

In 2021, the potentially dilutive impact from mandatory convertible preferred stock was calculated under the if-converted method until the mandatory conversion date. After the mandatory conversion date, the converted shares are included in weighted-average common shares outstanding for basic EPS. We converted all of our series A preferred stock into common stock on January 15, 2021 and all of our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for both the three months and six months ended June 30, 2021 excludes 4,256,725 potentially dilutive shares.

In January 2022, pursuant to Sempra’s share-based compensation plans, the Compensation and Talent Committee of Sempra’s board of directors granted 219,898 nonqualified stock options, 338,080 performance-based RSUs and 150,286 service-based RSUs.

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

COMPREHENSIVE INCOME

The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, 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 other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended June 30, 2022 and 2021
Sempra:
Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
OCI before reclassifications	1		37		1		39
Amounts reclassified from AOCI(2)	10		11		2		23
Net OCI(2)	11		48		3		62
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance at March 31, 2021	$	(69)	$	(239)	$	(91)	$	(399)
OCI before reclassifications(3)	(19)		(36)		(2)		(57)
Amounts reclassified from AOCI	—		10		2		12
Net OCI(3)	(19)		(26)		—		(45)
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at March 31, 2022 and June 30, 2022					$	(10)	$	(10)
Balance at March 31, 2021 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance at March 31, 2022			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)
Balance at March 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, 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 other postretirement benefits		Total accumulated other comprehensive income (loss)
	Six months ended June 30, 2022 and 2021
Sempra:
Balance as of December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		111		7		122
Amounts reclassified from AOCI(2)	10		15		4		29
Net OCI(2)	14		126		11		151
Balance as of June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications(3)	(24)		37		5		18
Amounts reclassified from AOCI	—		29		9		38
Net OCI(3)	(24)		66		14		56
Balance as of June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at December 31, 2021 and June 30, 2022					$	(10)	$	(10)
Balance at December 31, 2020 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance as of December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance as of June 30, 2022			$	(12)	$	(17)	$	(29)
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, 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 accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	13		19		Equity Earnings(1)
Foreign exchange instruments	(1)		—		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	—		(7)		Other (Expense) Income, Net
Total, before income tax	12		11
	(4)		(1)		Income Tax Expense
Total, net of income tax	8		10
	3		—		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	11	$	10
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	2	$	1	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total, before income tax	3		2
	(1)		—		Income Tax Expense
Total, net of income tax	$	2	$	2
Total reclassifications for the period, net of income  tax and NCI	$	14	$	12
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	—	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of income  tax	$	1	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	(1)	$	1	Interest Expense
Interest rate instruments	27		38		Equity Earnings(1)
Foreign exchange instruments	(2)		1		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Foreign exchange instruments	(1)		1		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	(6)		(1)		Other (Expense) Income, Net
Total, before income tax	17		40
	(5)		(9)		Income Tax Expense
Total, net of income tax	12		31
	3		(2)		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	15	$	29
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	4	$	3	Other (Expense) Income, Net
Amortization of prior service cost	2		2		Other (Expense) Income, Net
Settlement charges	—		7		Other (Expense) Income, Net
Total, before income tax	6		12
	(2)		(3)		Income Tax Expense
Total, net of income tax	$	4	$	9
Total reclassifications for the period, net of income  tax and NCI	$	20	$	38
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other Income (Expense), Net
Amortization of prior service cost	—		1		Other Income (Expense), Net
Total, before income tax	1		1
	—		—		Income Tax Expense
Total, net of income tax	$	1	$	1
Total reclassifications for the period, net of income  tax	$	2	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

For the three months and six months ended June 30, 2022 and 2021, reclassifications out of AOCI to net income were negligible for SDG&E.

SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Sempra Series A Preferred Stock

On January 15, 2021, we converted all 17,250,000 shares of series A preferred stock into 13,781,025 shares of our common stock based on a conversion rate of 0.7989 shares of our common stock for each issued and outstanding share of series A preferred stock. As a consequence, no shares of series A preferred stock were outstanding after January 15, 2021 and the 17,250,000 shares that were formerly series A preferred stock returned to the status of authorized and unissued shares of preferred stock.

Sempra Common Stock Repurchases

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

On April 6, 2022, we entered into an ASR program under which we prepaid $250 million to repurchase shares of our common stock in a share forward transaction. A total of 1,471,957 shares were purchased under this program at an average price of $169.84 per share. The total number of shares purchased was determined by dividing the $250 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of April 7, 2022 through April 25, 2022, minus a fixed discount. The ASR program was completed on April 25, 2022.

Other Noncontrolling Interests

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

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Sempra Infrastructure:
SI Partners	30.0	%	20.0	%	$	2,146	$	1,384
SI Partners subsidiaries(1)	0.1 - 16.6		0.1 - 16.6		46		34
Total Sempra					$	2,192	$	1,418

(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 in SI Partners to ADIA. On June 1, 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 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 $709 million, net of $12 million in transaction costs and $301 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.

At the closing of the sale of NCI in SI Partners to ADIA, SI Partners indirectly owned 99.9% of the outstanding shares of IEnova. To the extent we acquire additional shares of IEnova after the closing, such additional shares will be acquired by SI Partners, and KKR and ADIA will provide 20% and 10%, respectively, of the funding.

At the closing, KKR and ADIA (the Minority Partners) and Sempra entered into a second amended and restated agreement of limited partnership of SI Partners (the Amended LP Agreement), which governs their respective rights and obligations in respect of their ownership of SI Partners. Under the Amended LP Agreement, matters are decided generally by majority vote and the managers designated by Sempra, KKR and ADIA each, as a group, have voting power equivalent to the ownership percentage of their respective designating limited partner. Sempra maintains control of SI Partners. However, SI Partners and its controlled subsidiaries are prohibited from taking certain limited actions without the prior written approval of the Minority Partners (subject

to each Minority Partner maintaining certain ownership thresholds in SI Partners). The minority protections held by ADIA constitute a subset of the minority protections granted to KKR.

The terms of the Amended LP Agreement applicable to ADIA in relation to capital contributions and distributions are generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including limiting ADIA’s priority distribution rights to the failure of certain proposed projects to receive a positive final investment decision by a certain date or to achieve specified thresholds of projected internal rates of return or leverage. The transfer rights and restrictions and registration rights in the Amended LP Agreement applicable to ADIA are also generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including a general restriction on ADIA transferring its interests in SI Partners to third parties (other than pursuant to certain specified permitted transfers) for a specified period following its entry into the Amended LP Agreement.

SI Partners Subsidiaries. In May 2021, we acquired 381,015,194 publicly owned shares of IEnova in exchange for 12,306,777 newly issued shares of our common stock upon completion of our exchange offer launched in the U.S. and Mexico, which increased our ownership interest in IEnova from 70.2% to 96.4%. We acquired the IEnova shares at an exchange ratio of 0.0323 shares of our common stock for each one IEnova share. In connection with the exchange offer, we recorded a $1.4 billion decrease in equity held by NCI and an increase in Sempra’s shareholders’ equity of $1.4 billion, net of $12 million in transactions costs.

Following the exchange offer we completed in May 2021 and a subsequent cash tender offer we completed in September 2021, IEnova’s shares were delisted from the Mexican Stock Exchange effective October 15, 2021. In connection with the delisting, we are maintaining a trust for the purpose of purchasing the 1,212,981 IEnova shares that remained publicly owned as of the completion of the cash tender offer for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust was to be in place through the earlier of April 14, 2022 or the date on which we acquired all the remaining publicly owned IEnova shares. On April 13, 2022, the term of the trust was amended so that it will remain in place until we terminate it, subject to any maximum term under applicable Mexican law. As of August 1, 2022, an aggregate of 851,211 of the remaining publicly owned IEnova shares had been acquired by such trust.

TRANSACTIONS WITH AFFILIATES

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Sempra Infrastructure – IMG – Note due March 15, 2023(1)	$	626	$	2
Various affiliates	20		21
Total due from unconsolidated affiliates – current	$	646	$	23
Sempra Infrastructure – IMG – Note due March 15, 2022, net of allowance for credit losses of $1 at December 31, 2021(1)	$	—	$	637
Total due from unconsolidated affiliates – noncurrent	$	—	$	637
Sempra Infrastructure(2):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	(39)	$	(69)
5.5% Note due January 14, 2025	(22)		(21)
5.5% Note due July 16, 2025	(21)		(20)
5.5% Note due January 14, 2026	(18)		—
TAG – 5.74% Note due December 17, 2029	(182)		(177)
Total due to unconsolidated affiliates – noncurrent	$	(282)	$	(287)
SDG&E:
Sempra	$	(26)	$	(40)
SoCalGas	(30)		(48)
Various affiliates	(12)		(9)
Total due to unconsolidated affiliates – current	$	(68)	$	(97)
Income taxes due from Sempra(3)	$	21	$	19
SoCalGas:
SDG&E	$	30	$	48
Various affiliates	1		1
Total due from unconsolidated affiliates – current	$	31	$	49
Sempra	$	(36)	$	(36)
Total due to unconsolidated affiliates – current	$	(36)	$	(36)
Income taxes due from Sempra(3)	$	6	$	6

(1)    At December 31, 2021, represents a Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $691 U.S. dollar-equivalent at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps. In March 2022, Sempra Infrastructure amended and restated the revolving line of credit to a U.S. dollar-denominated note in the amount of $625 at a variable interest rate based on the adjusted 1-month Secured Overnight Financing Rate plus 180 bps (3.41% at June 30, 2022) and extended the maturity date to March 15, 2023. At June 30, 2022 and December 31, 2021, $1 and $2 of accrued interest receivable, respectively, is included in Due from Unconsolidated Affiliates – Current. In July 2022, this note receivable was paid in full.

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

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

The following table summarizes income statement information from unconsolidated affiliates.

INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Revenues	$	15	$	7	$	22	$	15
Cost of sales	—		—		—		11
Interest income	4		12		14		27
Interest expense	4		3		8		7
SDG&E:
Revenues	$	4	$	2	$	8	$	4
Cost of sales	26		27		50		55
SoCalGas:
Revenues	$	23	$	23	$	49	$	48
Cost of sales(1)	(4)		—		(4)		3

(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 6 below and in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

OTHER (EXPENSE) INCOME, NET

Other (expense) income, net, consists of the following:

OTHER (EXPENSE) INCOME, NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Allowance for equity funds used during construction	$	34	$	34	$	69	$	72
Investment (losses) gains, net(1)	(34)		19		(47)		28
(Losses) gains on interest rate and foreign exchange instruments, net	(1)		7		5		(23)
Foreign currency transaction (losses) gains, net(2)	(3)		26		(22)		7
Non-service components of net periodic benefit (cost) credit	(9)		(15)		32		14
Interest on regulatory balancing accounts, net	4		2		5		3
Sundry, net	8		(1)		(5)		6
Total	$	(1)	$	72	$	37	$	107
SDG&E:
Allowance for equity funds used during construction	$	21	$	22	$	42	$	45
Non-service components of net periodic benefit (cost) credit	(2)		(4)		9		5
Interest on regulatory balancing accounts, net	3		2		4		3
Sundry, net	—		2		1		4
Total	$	22	$	22	$	56	$	57
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	26	$	23
Non-service components of net periodic benefit (cost) credit	(6)		(9)		26		19
Interest on regulatory balancing accounts, net	1		—		1		—
Sundry, net	(4)		(4)		(15)		(5)
Total	$	4	$	(2)	$	38	$	37

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

(2)    Includes losses of $11 in the six months ended June 30, 2022 and gains of $28 and $5 in the three months and six months ended June 30, 2021, respectively, 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 Statements of Operations.

INCOME TAXES

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2022			2021			2022			2021
Sempra:
Income tax expense	$	80		$	139		$	414		$	297
Income before income taxes and equity earnings	$	364		$	281		$	1,029		$	1,049
Equity earnings, before income tax(1)	159			185			302			320
Pretax income	$	523		$	466		$	1,331		$	1,369
Effective income tax rate	15		%	30		%	31		%	22		%
SDG&E:
Income tax expense	$	42		$	33		$	106		$	78
Income before income taxes	$	218		$	219		$	516		$	476
Effective income tax rate	19		%	15		%	21		%	16		%
SoCalGas:
Income tax expense	$	19		$	8		$	103		$	102
Income before income taxes	$	107		$	103		$	525		$	604
Effective income tax rate	18		%	8		%	20		%	17		%

(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 or benefit, 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

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

In the six months ended June 30, 2022, we recognized income tax expense of $120 million for a deferred income tax liability related to outside basis differences in our foreign subsidiaries that we had previously considered to be indefinitely reinvested.

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NEW ACCOUNTING STANDARDS

6 Months Ended

Jun. 30, 2022

Accounting Changes and Error Corrections [Abstract]

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS

We describe below recent accounting pronouncements that have had or may have a significant effect on our results of operations, financial condition, cash flows or disclosures.

ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and

contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We adopted the standard on January 1, 2022 using a modified retrospective approach and the adoption did not materially impact our financial statements or per-share amounts.

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REVENUES

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

REVENUES

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.

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

DISAGGREGATED REVENUES
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2022
By major service line:
Utilities	$	1,250	$	1,347	$	20	$	(27)	$	2,590
Energy-related businesses	—		—		457		(14)		443
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
By market:
Gas	$	159	$	1,347	$	340	$	(19)	$	1,827
Electric	1,091		—		137		(22)		1,206
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Utilities regulatory revenues	149		154		—		—		303
Other revenues	—		—		212		(1)		211
Total revenues	$	1,399	$	1,501	$	689	$	(42)	$	3,547
	Six months ended June 30, 2022
By major service line:
Utilities	$	2,751	$	3,259	$	48	$	(56)	$	6,002
Energy-related businesses	—		—		749		(29)		720
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
By market:
Gas	$	489	$	3,259	$	569	$	(45)	$	4,272
Electric	2,262		—		228		(40)		2,450
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Utilities regulatory revenues	93		235		—		—		328
Other revenues	—		—		316		1		317
Total revenues	$	2,844	$	3,494	$	1,113	$	(84)	$	7,367

DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2021
By major service line:
Utilities	$	1,170	$	1,062	$	17	$	(25)	$	2,224
Energy-related businesses	—		—		260		(14)		246
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
By market:
Gas	$	162	$	1,062	$	185	$	(24)	$	1,385
Electric	1,008		—		92		(15)		1,085
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Utilities regulatory revenues	148		62		—		—		210
Other revenues	—		—		64		(3)		61
Total revenues	$	1,318	$	1,124	$	341	$	(42)	$	2,741
	Six months ended June 30, 2021
By major service line:
Utilities	$	2,386	$	2,719	$	44	$	(52)	$	5,097
Energy-related businesses	—		—		529		(15)		514
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
By market:
Gas	$	435	$	2,719	$	397	$	(48)	$	3,503
Electric	1,951		—		176		(19)		2,108
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Utilities regulatory revenues	269		(87)		—		—		182
Other revenues	—		—		217		(10)		207
Total revenues	$	2,655	$	2,632	$	790	$	(77)	$	6,000

REVENUES FROM CONTRACTS WITH CUSTOMERS

Remaining Performance Obligations

For contracts greater than one year, at June 30, 2022, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2022.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2022 (excluding first six months of 2022)	$	200	$	2
2023	384		4
2024	385		4
2025	384		4
2026	382		4
Thereafter	4,525		63
Total revenues to be recognized	$	6,260	$	81

(1)    Excludes intercompany transactions.

Contract Liabilities from Revenues from Contracts with Customers

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2022 or 2021. As we discuss in Note 11, Sempra Infrastructure drew against and fully exhausted Gazprom’s letters of credit in April 2022 due to Gazprom’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance. Gazprom has not paid its invoices since March 2022, so funds drawn from the letters of credit have been used to fully offset such nonpayment, which have been reflected as revenue from performance obligations satisfied during the reporting period. We expect that these funds will provide payment security from Gazprom through the end of 2024.

CONTRACT LIABILITIES
(Dollars in millions)
	2022		2021
Sempra:
Contract liabilities at January 1	$	(278)	$	(207)
Revenue from performance obligations satisfied during reporting period	86		49
Payments received in advance	(105)		(1)
Contract liabilities at June 30(1)	$	(297)	$	(159)
SDG&E:
Contract liabilities at January 1	$	(83)	$	(87)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(1)	$	(81)	$	(85)

(1)     Balances at June 30, 2022 include $81 and $4 in Other Current Liabilities and $216 and $77 in Deferred Credits and Other on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets, respectively.

Receivables from Revenues from Contracts with Customers

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Accounts receivable – trade, net	$	1,620	$	1,886
Accounts receivable – other, net	13		19
Due from unconsolidated affiliates – current(1)	5		2
Other long-term assets(2)	32		70
Total	$	1,670	$	1,977
SDG&E:
Accounts receivable – trade, net	$	685	$	715
Accounts receivable – other, net	11		9
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets(2)	17		25
Total	$	716	$	751
SoCalGas:
Accounts receivable – trade, net	$	722	$	1,084
Accounts receivable – other, net	2		10
Other long-term assets(2)	15		45
Total	$	739	$	1,139

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

(2)     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.

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REGULATORY MATTERS

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERS

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2022		December 31, 2021
SDG&E:
Fixed-price contracts and other derivatives	$	(24)	$	(50)
Deferred income taxes recoverable in rates	176		125
Pension and other postretirement benefit plan obligations	(8)		(7)
Removal obligations	(2,185)		(2,251)
Environmental costs	61		62
Sunrise Powerlink fire mitigation	121		122
Regulatory balancing accounts(1)(2)
Commodity – electric	246		77
Gas transportation	33		49
Safety and reliability	80		67
Public purpose programs	(117)		(107)
Wildfire mitigation plan	255		178
Liability insurance premium	102		110
Other balancing accounts	(17)		207
Other regulatory assets, net(2)	132		119
Total SDG&E	(1,145)		(1,299)
SoCalGas:
Deferred income taxes recoverable in rates	113		44
Pension and other postretirement benefit plan obligations	39		51
Employee benefit costs	31		31
Removal obligations	(603)		(627)
Environmental costs	34		34
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(46)		(146)
Safety and reliability	425		339
Public purpose programs	(213)		(183)
Liability insurance premium	18		16
Other balancing accounts	125		42
Other regulatory assets, net(2)	153		142
Total SoCalGas	76		(257)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		77
Total Sempra	$	(992)	$	(1,479)

(1)    At June 30, 2022 and December 31, 2021, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $453 and $358, respectively, and for SoCalGas was $601 and $410, 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 rates designed 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 are proposing post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 12% at SDG&E and approximately 6% to 8% at SoCalGas. SDG&E and SoCalGas have requested that the CPUC issue a final decision by the end of 2023 with new rates to be implemented in January 2024. SDG&E proposes to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in mid-2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole to have its cost of capital determined in lieu of the CCM.

Authorized Cost of Capital, Subject to the CCM

In December 2019, the CPUC approved the cost of capital (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index.

AUTHORIZED CPUC COST OF CAPITAL, SUBJECT TO THE CCM
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	%	4.59	%	2.08	%	Long-Term Debt	45.60	%	4.23	%	1.93	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.20		5.30		Common Equity	52.00		10.05		5.23
100.00	%			7.55	%		100.00	%			7.30	%

For the measurement period that ended September 30, 2021, the CCM would trigger for SDG&E if the CPUC determines that the CCM should be implemented because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event such that the CCM should not apply. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects to receive a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022.

Proposed Cost of Capital

In April 2022, SDG&E and SoCalGas each filed applications with the CPUC to update their cost of capital (shown in the table below), which would become effective on January 1, 2023 and would remain in effect through December 31, 2025, subject to the CCM if it remains in place as proposed. SDG&E and SoCalGas expect to receive a final decision by the end of 2022.

PROPOSED CPUC COST OF CAPITAL
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
46.00	%	3.87	%	1.78	%	Long-Term Debt	45.60	%	3.89	%	1.77	%
—		—		—		Preferred Equity	0.40		6.00		0.02
54.00		10.55		5.70		Common Equity	54.00		10.75		5.81
100.00	%			7.48	%		100.00	%			7.60	%

SOCALGAS

OSCs – Energy Efficiency and Advocacy

In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. In February 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 became the final decision of the CPUC in March 2022.

In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, a CPUC commissioner issued an alternative decision finding that there were violations of certain legal principles and imposing a financial penalty of $150,000. The alternative decision was adopted by the CPUC as the final decision in April 2022SAN ONOFRE NUCLEAR GENERATING STATION

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

NUCLEAR DECOMMISSIONING AND FUNDING

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost.

The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the Samuel Lawrence Foundation filed a notice of appeal. To date, decommissioning work has not been interrupted as a result of this writ petition.

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 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 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 9.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	43	$	1	$	(1)	$	43
Municipal bonds(2)	305		1		(13)		293
Other securities(3)	256		1		(20)		237
Total debt securities	604		3		(34)		573
Equity securities	109		187		(8)		288
Short-term investments, primarily cash equivalents	15		—		—		15
Receivables (payables), net	(13)		—		—		(13)
Total	$	715	$	190	$	(42)	$	863
	December 31, 2021
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	56	$	—	$	—	$	56
Municipal bonds	309		13		(1)		321
Other securities	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012

(1)    Maturity dates are 2023-2052.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2022-2072.

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

SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Proceeds from sales	$	155	$	254	$	397	$	542
Gross realized gains	3		18		14		39
Gross realized losses	(7)		(1)		(11)		(3)

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

SDG&E’s ARO related to decommissioning costs for SONGS Units 1, 2 and 3 was $557 million at June 30, 2022 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

NUCLEAR INSURANCE

The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.1 million of retrospective premiums based on overall member claims.

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ACQUISITIONS AND DIVESTITURES

6 Months Ended

Jun. 30, 2022

Business Combinations [Abstract]

ACQUISITIONS AND DIVESTITURES

ACQUISITIONS AND DIVESTITURES

ACQUISITION

Sempra Infrastructure

ESJ

In March 2021, Sempra Infrastructure completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of $65 million (net of $14 million of acquired cash and cash equivalents) plus the assumption of $277 million in debt (including $94 million owed from ESJ to Sempra Infrastructure that eliminates upon consolidation). Sempra Infrastructure previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased Sempra Infrastructure’s ownership interest in ESJ from 50% to 100%. We accounted for this asset acquisition using a cost accumulation

model whereby the cost of the acquisition and carrying value of our previously held interest in ESJ ($34 million) were allocated to assets acquired ($458 million) and liabilities assumed ($345 million) based on their relative fair values. ESJ owns a fully operating wind power generation facility with a nameplate capacity of 155 MW that is fully contracted by SDG&E under a long-term PPA. Sempra Infrastructure recorded a $190 million intangible asset for the relative fair value of the PPA that will be amortized over a period of 14 years against revenues. On January 15, 2022, ESJ completed construction and began commercial operation of a second wind power generation facility with a nameplate capacity of 108 MW that is also fully contracted by SDG&E under a long-term PPA.

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INVESTMENTS IN UNCONSOLIDATED ENTITIES

6 Months Ended

Jun. 30, 2022

Investments [Abstract]

INVESTMENTS IN UNCONSOLIDATED ENTITIES

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 12 for information on equity earnings and losses, both before and net of income tax, by segment. See Note 1 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.

We provide additional information concerning our equity method investments in Notes 5 and 6 of the Notes to Consolidated Financial Statements in the Annual Report.

SEMPRA TEXAS UTILITIES

Oncor Holdings

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

In the six months ended June 30, 2022 and 2021, Sempra contributed $171 million and $100 million, respectively, to Oncor Holdings, and Oncor Holdings distributed $170 million and $162 million, respectively, to Sempra.

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Operating revenues	$	1,293	$	1,147	$	2,542	$	2,286
Operating expenses	(908)		(836)		(1,805)		(1,665)
Income from operations	385		311		737		621
Interest expense	(108)		(102)		(216)		(204)
Income tax expense	(52)		(34)		(94)		(70)
Net income	226		167		417		332
Noncontrolling interest held by Texas Transmission Investment LLC	(46)		(34)		(84)		(67)
Earnings attributable to Sempra(1)	180		133		333		265

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

SEMPRA INFRASTRUCTURE

Cameron LNG JV

In the six months ended June 30, 2022, Sempra Infrastructure contributed $10 million to Cameron LNG JV. In the six months ended June 30, 2022 and 2021, Cameron LNG JV distributed to Sempra Infrastructure $233 million and $378 million, respectively, of which $165 million relates to the distribution from Cameron LNG JV’s SDSRA that we discuss below.

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 $21 million at June 30, 2022, 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 its 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, as amended on June 29, 2021, 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 will 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 will recognize 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 9). At June 30, 2022, the fair value of the Support Agreement was $16 million, of which $7 million is included in Other Current Assets and $9 million is included in Other Long-Term Assets on Sempra’s Condensed Consolidated Balance Sheet.

ESJ

As we discuss in Note 5, in March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, Sempra Infrastructure owned 50% of ESJ and accounted for its interest as an equity method investment. In the six months ended June 30, 2021, ESJ distributed a $4 million return of investment to IEnova.

TAG

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

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DEBT AND CREDIT FACILITIES

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES

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

SHORT-TERM DEBT

Committed Lines of Credit

At June 30, 2022, Sempra had an aggregate capacity of $9.5 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.

COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2022
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	May 2024	$	3,185	$	(42)	$	—	$	3,143
Sempra	May 2024	1,250		—		—		1,250
SDG&E	May 2024	1,500		—		—		1,500
SoCalGas	May 2024	750		—		—		750
SI Partners	November 2024	1,000		—		(285)		715
IEnova	September 2023	350		—		(310)		40
IEnova	February 2024	1,500		—		—		1,500
Total		$	9,535	$	(42)	$	(595)	$	8,898

Sempra, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65% at the end of each quarter. At June 30, 2022, each entity was in compliance with this ratio under its respective credit facility.

SI Partners must maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in its credit facility) of no more than 5.25 to 1.00 as of the end of each quarter. At June 30, 2022, SI Partners was in compliance with this ratio.

Uncommitted Lines of Credit

In addition to our committed lines of credit, Sempra Infrastructure’s foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $570 million at June 30, 2022, which are generally used for working capital requirements. We reflect amounts outstanding under these uncommitted lines of credit before reductions of any unamortized discounts.

FOREIGN UNCOMMITTED LINES OF CREDIT
(Dollars and U.S. dollar equivalent in millions)
			June 30, 2022
Borrower	Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
IEnova	September 2022	U.S. dollars	$	250	$	(250)	$	—
ECA LNG Phase 1(1)	August 2023	U.S. dollars or Mexican pesos	200		(32)		168
IEnova(2)	October 2023	U.S. dollars	100		(36)		64
IEnova	October 2023	U.S. dollars or Mexican pesos	20		—		20
Total			$	570	$	(318)	$	252

(1)    In March 2022, the facility was amended to increase the borrowing capacity from $100 to $200.

(2)    Advances are due in full within 180 days of the disbursement date, which may be extended in increments of 180 days provided that no advance may have a maturity date that falls more than three years after the date of disbursement.

Uncommitted Letters of Credit

Outside of our domestic and foreign credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At June 30, 2022, we had approximately $730 million in standby letters of credit outstanding under these agreements.

UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		June 30, 2022
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2023 to May 2023	$	15
SoCalGas	November 2022 to October 2023	20
Sempra Infrastructure	July 2022 to October 2043	525
Parent and other	September 2022 to June 2023	170
Total		$	730

Term Loan

In July 2022, SoCalGas entered into an $800 million, 364-day term loan agreement with a maturity date of July 6, 2023. SoCalGas may request one borrowing of up to $800 million through October 7, 2022. The borrowings will bear interest at benchmark rates plus 70 bps and are due in full upon maturity. The term loan provides SoCalGas with additional liquidity outside of its line of credit, which may include payment of a portion of the costs associated with civil litigation related to the Leak.

Weighted-Average Interest Rates

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

WEIGHTED-AVERAGE INTEREST RATES
	June 30, 2022		December 31, 2021
Sempra	2.70	%	0.60	%
SDG&E	—		0.65
SoCalGas	—		0.21

LONG-TERM DEBT

Sempra

In March 2022, we issued $750 million aggregate principal amount of 3.30% senior unsecured notes due in full upon maturity on April 1, 2025 and received proceeds of $745 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million), and $500 million of 3.70% senior unsecured notes due in full upon maturity on April 1, 2029 and received proceeds of $494 million (net of debt discount, underwriting discounts and debt issuance costs of $6 million). Each series of the notes is redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. We used a portion of the net proceeds for general corporate purposes and repayment of commercial paper.

SDG&E

In February 2022, SDG&E entered into a $400 million, two-year term loan with a maturity date of February 18, 2024. SDG&E borrowed $200 million in the three months ended March 31, 2022 and an additional $200 million in the three months ended June 30, 2022. The borrowings bear interest at benchmark rates plus 62.5 bps and are due in full upon maturity. The margin is based on SDG&E’s long-term senior unsecured credit rating. SDG&E used the net proceeds for repayment of commercial paper and for general corporate purposes.

In March 2022, SDG&E issued $500 million aggregate principal amount of 3.00% first mortgage bonds due in full upon maturity on March 15, 2032 and received proceeds of $494 million (net of debt discount, underwriting discounts and debt issuance costs of $6 million), and $500 million aggregate principal amount of 3.70% first mortgage bonds due in full upon maturity on March 15, 2052 and received proceeds of $492 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). Each of 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 a portion of the net proceeds for repayment of commercial paper and its 364-day term loan

and intends to use the remaining proceeds for capital expenditures and other general corporate purposes.

SoCalGas

In March 2022, SoCalGas issued $700 million aggregate principal amount of 2.95% senior unsecured notes due in full upon maturity on April 15, 2027 and received proceeds of $691 million (net of debt discount, underwriting discounts and debt issuance costs of $9 million). The notes are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. SoCalGas used a portion of the net proceeds for repayment of commercial paper and intends to use the remaining proceeds for general corporate purposes, which may include payment of a portion of the costs relating to civil litigation pertaining to the Leak.

Sempra Infrastructure

SI Partners

In January 2022, SI Partners completed a private offering of $400 million in aggregate principal of 3.25% senior notes due in full upon maturity on January 15, 2032 to “qualified institutional buyers” as defined in Rule 144A under the Securities Act of 1933, as amended (the Securities Act), and non-U.S. persons outside the U.S. under Regulation S under the Securities Act. The notes are senior unsecured obligations that rank equally with all of SI Partners’ existing and future outstanding unsecured senior indebtedness and are redeemable prior to maturity, subject to their terms, and in certain circumstances subject to make-whole provisions. Sempra Infrastructure received proceeds of $390 million (net of debt discount, underwriting discounts and debt issuance costs of $10 million). Sempra Infrastructure used the net proceeds for general corporate purposes, including the repayment of certain indebtedness of its subsidiaries.

ECA LNG Phase 1

In December 2020, ECA LNG Phase 1 entered into a five-year loan agreement with a syndicate of nine banks for an aggregate principal amount of up to $1.6 billion. Sempra and TotalEnergies SE have provided guarantees for repayment of the loans plus accrued and unpaid interest based on their proportionate ownership interest in ECA LNG Phase 1 of 83.4% and 16.6%, respectively. At June 30, 2022 and December 31, 2021, $455 million and $341 million, respectively, was outstanding under the loan agreement, with a weighted-average interest rate of 4.37% and 2.93%, respectively.

In July 2022, ECA LNG Phase 1 replaced Sempra with IEnova as the guarantor and replaced two of the nine banks and their combined principal commitment of $203 million ($61 million of which was outstanding at June 30, 2022) with a shareholder loan from IEnova, thereby reducing the syndicate to seven banks.

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DERIVATIVE FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE FINANCIAL INSTRUMENTS

DERIVATIVE FINANCIAL INSTRUMENTS

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

In certain cases, we apply the normal purchase or sale exception to 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 hedge termination costs on interest rate swaps as financing activities and settlements of other derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows.

HEDGE ACCOUNTING

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

ENERGY DERIVATIVES

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

▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, 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 that have been filed with and approved by the CPUC. 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 Electric Fuel and Purchased Power or in Cost of Natural Gas.

▪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 their assets which support the following businesses: LNG, natural gas transportation 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. Certain of these derivatives may also be designated as cash flow hedges.

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

The following table summarizes net energy derivative volumes.

NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
Commodity	Unit of measure	June 30, 2022	December 31, 2021
Sempra:
Natural gas	MMBtu	193	184
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SDG&E:
Natural gas	MMBtu	10	7
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SoCalGas:
Natural gas	MMBtu	141	201

INTEREST RATE DERIVATIVES

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

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

INTEREST RATE DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	436	2022-2034	$	462	2022-2034

FOREIGN CURRENCY DERIVATIVES

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

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

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2022-2023	$	306	2022-2023
Other foreign currency derivatives	65		2022-2023	106		2022-2023

FINANCIAL STATEMENT PRESENTATION

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2022
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	5	$	27	$	—	$	—
Foreign exchange instruments	—		—		(2)		—
Interest rate and foreign exchange instruments	—		—		(117)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	182		91		(182)		(89)
Associated offsetting commodity contracts	(167)		(32)		167		32
Commodity contracts subject to rate recovery	27		25		(22)		(1)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		111		(153)		(58)
Additional cash collateral for commodity contracts not subject to rate recovery	76		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	48		—		—		—
Total(1)	$	168	$	111	$	(153)	$	(58)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	26	$	25	$	(14)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	23		25		(11)		—
Additional cash collateral for commodity contracts subject to rate recovery	36		—		—		—
Total(1)	$	59	$	25	$	(11)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	1	$	—	$	(8)	$	(1)
Net amounts presented on the balance sheet	1		—		(8)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	12		—		—		—
Total	$	13	$	—	$	(8)	$	(1)

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2021
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	6	$	(6)	$	(2)
Foreign exchange instruments	1		1		(1)		—
Interest rate and foreign exchange instruments	—		—		(1)		(130)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	136		11		(122)		(10)
Associated offsetting commodity contracts	(93)		(8)		93		8
Commodity contracts subject to rate recovery	38		52		(58)		—
Associated offsetting commodity contracts	(8)		—		8		—
Net amounts presented on the balance sheet	74		62		(87)		(134)
Additional cash collateral for commodity contracts not subject to rate recovery	58		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	46		—		—		—
Total(1)	$	178	$	62	$	(87)	$	(134)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	34	$	52	$	(20)	$	—
Associated offsetting commodity contracts	(5)		—		5		—
Net amounts presented on the balance sheet	29		52		(15)		—
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(1)	$	57	$	52	$	(15)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4	$	—	$	(38)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	1		—		(35)		—
Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total	$	19	$	—	$	(35)	$	—

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

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

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	13	$	(6)	Interest Expense	$	—	$	1
Interest rate instruments	50		(32)		Equity Earnings(1)	(13)		(19)
Foreign exchange instruments	—		(1)		Revenues: Energy- Related Businesses	1		—
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	—		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	4		7		Interest Expense	1		—
					Other (Expense) Income, Net	—		7
Total	$	67	$	(33)		$	(12)	$	(11)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	—
	Six months ended June 30,					Six months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	35	$	20	Interest Expense	$	1	$	(1)
Interest rate instruments	144		51		Equity Earnings(1)	(27)		(38)
Foreign exchange instruments	(3)		2		Revenues: Energy- Related Businesses	2		(1)
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	(2)		2		Equity Earnings(1)	1		(1)
Interest rate and foreign exchange instruments	13		1		Interest Expense	1		—
					Other (Expense) Income, Net	6		1
Total	$	187	$	76		$	(17)	$	(40)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	—

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

For Sempra, we expect that net gains before NCI of $6 million, which are net of income tax expense, that are currently recorded in AOCI (with net gains of $11 million attributable to NCI) related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature.

For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at June 30, 2022 is approximately 12 years for Sempra. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 17 years.

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

UNDESIGNATED DERIVATIVE IMPACTS
(Dollars in millions)
		Pretax (loss) gain on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2022		2021		2022		2021
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(151)	$	(142)	$	(228)	$	(190)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(4)		—		(4)		2
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	(24)		41		(6)		43
Foreign exchange instruments	Other (Expense) Income, Net	—		—		—		(24)
Total		$	(179)	$	(101)	$	(238)	$	(169)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	(24)	$	41	$	(6)	$	43
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(4)	$	—	$	(4)	$	2

CONTINGENT FEATURES

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

For Sempra, the total fair value of this group of derivative instruments in a liability position at June 30, 2022 and December 31, 2021 was $17 million and $88 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at June 30, 2022 and December 31, 2021 was $9 million and $36 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at June 30, 2022 or December 31, 2021. At June 30, 2022, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $17 million and $9 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.

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FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

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

RECURRING FAIR VALUE MEASURES

The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2022 and December 31, 2021. 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, 2021.

The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 8 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 derivatives 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 6, 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)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Short-term investments held in Rabbi Trust	50		—		—		50
Interest rate instruments	—		32		—		32
Commodity contracts not subject to rate recovery	—		74		—		74
Effect of netting and allocation of collateral(2)	76		—		—		76
Commodity contracts subject to rate recovery	13		1		35		49
Effect of netting and allocation of collateral(2)	32		10		6		48
Support Agreement, net of related guarantee fees	—		—		16		16
Total	$	499	$	665	$	57	$	1,221
Liabilities:
Foreign exchange instruments	$	—	$	2	$	—	$	2
Interest rate and foreign exchange instruments	—		117		—		117
Commodity contracts not subject to rate recovery	—		72		—		72
Commodity contracts subject to rate recovery	—		18		2		20
Total	$	—	$	209	$	2	$	211

(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)
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Short-term investments held in Rabbi Trust	81		—		—		81
Interest rate instruments	—		6		—		6
Foreign exchange instruments	—		2		—		2
Commodity contracts not subject to rate recovery	—		46		—		46
Effect of netting and allocation of collateral(2)	58		—		—		58
Commodity contracts subject to rate recovery	12		1		69		82
Effect of netting and allocation of collateral(2)	31		9		6		46
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	601	$	649	$	82	$	1,332
Liabilities:
Interest rate instruments	$	—	$	8	$	—	$	8
Foreign exchange instruments	—		1		—		1
Interest rate and foreign exchange instruments	—		131		—		131
Commodity contracts not subject to rate recovery	—		31		—		31
Commodity contracts subject to rate recovery	—		35		15		50
Total	$	—	$	206	$	15	$	221

(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)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Commodity contracts subject to rate recovery	13		—		35		48
Effect of netting and allocation of collateral(2)	30		—		6		36
Total	$	371	$	548	$	41	$	960
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	2	$	11
Total	$	—	$	9	$	2	$	11
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Commodity contracts subject to rate recovery	12		—		69		81
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	453	$	585	$	75	$	1,113
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	15	$	15
Total	$	—	$	—	$	15	$	15

(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)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	2		10		—		12
Total	$	2	$	11	$	—	$	13
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	—	$	9
Total	$	—	$	9	$	—	$	9
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	9		9		—		18
Total	$	9	$	10	$	—	$	19
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	35	$	—	$	35
Total	$	—	$	35	$	—	$	35

(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 June 30,
	2022		2021
Balance at April 1	$	58	$	62
Realized and unrealized (losses) gains	(30)		8
Allocated transmission instruments	(6)		(2)
Settlements	11		12
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(23)	$	14
	Six months ended June 30,
	2022		2021
Balance at January 1	$	54	$	69
Realized and unrealized (losses) gains	(23)		6
Allocated transmission instruments	(6)		(2)
Settlements	8		7
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(18)	$	12

(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. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments.

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
2022	$	(3.67)	to	$	6.96	$	(0.70)
2021	(1.81)		to	14.11		(0.12)

The impact associated with discounting is negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a significantly higher (lower) fair value measurement. We summarize CRR volumes in Note 8.

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

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2022	$	25.25	to	$	125.00	$	66.36
2021		22.45	to		151.90		49.27

A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 8.

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

Sempra Infrastructure

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

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2022		2021
Balance at April 1	$	12	$	3
Realized and unrealized gains(1)	6		3
Settlements	(2)		(2)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	5	$	2
	Six months ended June 30,
	2022		2021
Balance at January 1	$	7	$	3
Realized and unrealized gains(1)	14		5
Settlements	(5)		(4)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	13	$	4

(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 $9 in Other Long-term Assets at June 30, 2022 on Sempra’s Condensed Consolidated Balance Sheet.

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

Fair Value of Financial Instruments

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

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2022
Sempra:
Short-term amounts due from unconsolidated affiliates(1)	$	626	$	—	$	630	$	—	$	630
Long-term note receivable(2)	310		—		—		278		278
Long-term amounts due to unconsolidated affiliates	282		—		251		—		251
Total long-term debt(3)	23,924		—		21,709		—		21,709
SDG&E:
Total long-term debt(4)	$	7,800	$	—	$	7,102	$	—	$	7,102
SoCalGas:
Total long-term debt(5)	$	5,459	$	—	$	5,110	$	—	$	5,110
	December 31, 2021
Sempra:
Long-term note receivable(2)	$	300	$	—	$	—	$	327	$	327
Long-term amounts due from unconsolidated affiliates(1)	640		—		642		—		642
Long-term amounts due to unconsolidated affiliates	287		—		295		—		295
Total long-term debt(3)	20,099		—		22,126		—		22,126
SDG&E:
Total long-term debt(4)	$	6,417	$	—	$	7,236	$	—	$	7,236
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,367	$	—	$	5,367

(1)    Before allowances for credit losses of $1 at December 31, 2021. Includes $1 and $2 of accrued interest receivable at June 30, 2022 and December 31, 2021, respectively, in Due From Unconsolidated Affiliates – Current.

(2)    Before allowances for credit losses of $7 and $8 at June 30, 2022 and December 31, 2021, respectively. Excludes unamortized transaction costs of $5 at both June 30, 2022 and December 31, 2021, respectively.

(3)    Before reductions of unamortized discount and debt issuance costs of $294 and $260 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,334 and $1,335 at June 30, 2022 and December 31, 2021, respectively.

(4)    Before reductions of unamortized discount and debt issuance costs of $73 and $61 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,266 and $1,274 at June 30, 2022 and December 31, 2021, respectively.

(5)    Before reductions of unamortized discount and debt issuance costs of $43 and $36 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $68 and $61 at June 30, 2022 and December 31, 2021, respectively.

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

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SAN ONOFRE NUCLEAR GENERATING STATION

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

SAN ONOFRE NUCLEAR GENERATING STATION

REGULATORY MATTERS

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

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2022		December 31, 2021
SDG&E:
Fixed-price contracts and other derivatives	$	(24)	$	(50)
Deferred income taxes recoverable in rates	176		125
Pension and other postretirement benefit plan obligations	(8)		(7)
Removal obligations	(2,185)		(2,251)
Environmental costs	61		62
Sunrise Powerlink fire mitigation	121		122
Regulatory balancing accounts(1)(2)
Commodity – electric	246		77
Gas transportation	33		49
Safety and reliability	80		67
Public purpose programs	(117)		(107)
Wildfire mitigation plan	255		178
Liability insurance premium	102		110
Other balancing accounts	(17)		207
Other regulatory assets, net(2)	132		119
Total SDG&E	(1,145)		(1,299)
SoCalGas:
Deferred income taxes recoverable in rates	113		44
Pension and other postretirement benefit plan obligations	39		51
Employee benefit costs	31		31
Removal obligations	(603)		(627)
Environmental costs	34		34
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(46)		(146)
Safety and reliability	425		339
Public purpose programs	(213)		(183)
Liability insurance premium	18		16
Other balancing accounts	125		42
Other regulatory assets, net(2)	153		142
Total SoCalGas	76		(257)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		77
Total Sempra	$	(992)	$	(1,479)

(1)    At June 30, 2022 and December 31, 2021, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $453 and $358, respectively, and for SoCalGas was $601 and $410, 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 rates designed 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 are proposing post-test year revenue requirement changes using various mechanisms that are estimated to result in annual increases of approximately 8% to 12% at SDG&E and approximately 6% to 8% at SoCalGas. SDG&E and SoCalGas have requested that the CPUC issue a final decision by the end of 2023 with new rates to be implemented in January 2024. SDG&E proposes to submit separate requests in its GRC for review and recovery of its wildfire mitigation plan costs in mid-2023 for costs incurred from 2019 through 2022 and in mid-2024 for costs incurred in 2023.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. Alternatively, each of SDG&E and SoCalGas is permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole to have its cost of capital determined in lieu of the CCM.

Authorized Cost of Capital, Subject to the CCM

In December 2019, the CPUC approved the cost of capital (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index.

AUTHORIZED CPUC COST OF CAPITAL, SUBJECT TO THE CCM
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	%	4.59	%	2.08	%	Long-Term Debt	45.60	%	4.23	%	1.93	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.20		5.30		Common Equity	52.00		10.05		5.23
100.00	%			7.55	%		100.00	%			7.30	%

For the measurement period that ended September 30, 2021, the CCM would trigger for SDG&E if the CPUC determines that the CCM should be implemented because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event such that the CCM should not apply. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects to receive a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022.

Proposed Cost of Capital

In April 2022, SDG&E and SoCalGas each filed applications with the CPUC to update their cost of capital (shown in the table below), which would become effective on January 1, 2023 and would remain in effect through December 31, 2025, subject to the CCM if it remains in place as proposed. SDG&E and SoCalGas expect to receive a final decision by the end of 2022.

PROPOSED CPUC COST OF CAPITAL
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
46.00	%	3.87	%	1.78	%	Long-Term Debt	45.60	%	3.89	%	1.77	%
—		—		—		Preferred Equity	0.40		6.00		0.02
54.00		10.55		5.70		Common Equity	54.00		10.75		5.81
100.00	%			7.48	%		100.00	%			7.60	%

SOCALGAS

OSCs – Energy Efficiency and Advocacy

In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. In February 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 became the final decision of the CPUC in March 2022.

In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, a CPUC commissioner issued an alternative decision finding that there were violations of certain legal principles and imposing a financial penalty of $150,000. The alternative decision was adopted by the CPUC as the final decision in April 2022SAN ONOFRE NUCLEAR GENERATING STATION

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

NUCLEAR DECOMMISSIONING AND FUNDING

As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost.

The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the Samuel Lawrence Foundation filed a notice of appeal. To date, decommissioning work has not been interrupted as a result of this writ petition.

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 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 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 9.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	43	$	1	$	(1)	$	43
Municipal bonds(2)	305		1		(13)		293
Other securities(3)	256		1		(20)		237
Total debt securities	604		3		(34)		573
Equity securities	109		187		(8)		288
Short-term investments, primarily cash equivalents	15		—		—		15
Receivables (payables), net	(13)		—		—		(13)
Total	$	715	$	190	$	(42)	$	863
	December 31, 2021
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	56	$	—	$	—	$	56
Municipal bonds	309		13		(1)		321
Other securities	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012

(1)    Maturity dates are 2023-2052.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2022-2072.

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

SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Proceeds from sales	$	155	$	254	$	397	$	542
Gross realized gains	3		18		14		39
Gross realized losses	(7)		(1)		(11)		(3)

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

SDG&E’s ARO related to decommissioning costs for SONGS Units 1, 2 and 3 was $557 million at June 30, 2022 and is based on a cost study prepared in 2020 that is pending CPUC approval, which SDG&E expects to receive in 2023.

NUCLEAR INSURANCE

The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirement of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.1 million of retrospective premiums based on overall member claims.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

Sempra Infrastructure

Energía Costa Azul

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

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

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

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

In addition, four cases involving two adjacent areas of real property on which part of the ECA Regas Facility is situated, each brought by a single plaintiff or her descendants, remain pending against the facility, as follows:

▪The first disputed area is subject to a claim in the federal Agrarian Court that has been ongoing since 2006, 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 final federal appeal against the appellate court ruling. A final ruling from the Federal Collegiate Circuit Court is pending.

▪The second disputed area is a parcel adjacent to the ECA Regas Facility that allegedly overlaps with land on which the ECA Regas Facility is situated, which is subject to a claim in the federal Agrarian Court and two claims in Mexican civil courts. The ECA Regas Facility first bought the property from the federal government in 2003; however, to resolve an ownership controversy, in 2008, the ECA Regas Facility reached a financial settlement with the plaintiff to eliminate an adverse claim to its title. Nevertheless, the plaintiff sued in 2013 for the nullity of both titles. The Agrarian Court ruled in favor of the plaintiff in May 2021, nullifying the first property title. Sempra Infrastructure appealed the ruling in July 2021. In May 2022, Sempra Infrastructure won the appeal and the plaintiff’s claims were dismissed, which the plaintiff has appealed. The ECA Regas Facility continues to hold the second property title to the land. The two civil court proceedings, which seek to invalidate the contract by which the ECA Regas Facility purchased for the second time the applicable parcel of land on which the ECA Regas Facility is situated on the grounds that the purchase price was allegedly unfair, are progressing at different stages. In the first civil case, initiated in 2013, the court ruled in favor of the ECA Regas Facility, and the final decision was affirmed on a federal appeal. The descendants of the same plaintiff filed the second civil case in 2019, which was dismissed by the court. However, the dismissal has been appealed, which is pending the appellate court’s ruling. In April 2022, the ECA Regas Facility entered into a settlement agreement with the plaintiff, whereby the plaintiff has agreed to recognize the ECA Regas Facility as the sole owner of the property and waive any current or future rights over the property, or any other properties related to the ECA Regas Facility. The settlement agreement is pending court approval and would definitively resolve all three pending cases.

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

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

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

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

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

Customer Dispute. In May 2020, the two third-party capacity customers at the ECA Regas Facility, Shell Mexico and Gazprom, asserted that a 2019 update of the general terms and conditions for service at the facility, as approved by the CRE, resulted in a breach of contract by Sempra Infrastructure and a force majeure event. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and Gazprom joined the proceeding, and a hearing was held in October 2021. The International Court of Arbitration issued a final, non-appealable decision dated April 27, 2022 in favor of Sempra Infrastructure dismissing all claims and confirming the contracts remain in force. Shell Mexico submitted a request to the International Court of Arbitration, and Gazprom joined the request, to issue an additional decision, asserting that two of the claims were not addressed in the ruling. Sempra Infrastructure filed a response and requested that any additional decision by the International Court of Arbitration be incorporated into the original decision as one, final ruling for clarity to aid in enforcement proceedings should they become necessary.

Citing the alleged breach, Shell Mexico stopped making payments under its LNG storage and regasification agreement. Due to nonpayment, Sempra Infrastructure drew against Shell Mexico’s letters of credit provided as payment security until they were fully exhausted in March 2022 and this customer has not resumed making payments. Although Gazprom had previously been making regular monthly payments under its LNG storage and regasification agreement, Sempra Infrastructure drew against and fully exhausted Gazprom’s letters of credit in April 2022 due to Gazprom’s non-renewal of such letters of credit as required under the agreement. Gazprom has not paid its invoices since March 2022, so funds drawn from the letters of credit have been used to fully offset such nonpayment. We expect that these funds will provide payment security from Gazprom through the end of 2024.

In addition to the arbitration proceeding, Shell Mexico also filed constitutional claims against the CRE’s approval of the general terms and conditions for service at the facility and against the issuance of the liquefaction permit. Shell Mexico’s request for an injunction against the general terms and conditions was denied, and the ruling was upheld on appeal. The request for an injunction against the liquefaction permit was denied, and the decision was vacated and remanded on appeal to the First District Court in Administrative Matters, which again denied the injunction. The case on the injunction request was then heard again by the appellate court. A hearing was held on the merits and a decision is pending.

Sonora Pipeline

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

Following the start of commercial operations of the Guaymas-El Oro segment, Sempra Infrastructure reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 2017 and, as a result, Sempra Infrastructure declared a force majeure event. In 2017, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory, which has prevented Sempra Infrastructure from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of Sempra Infrastructure and held that the Yaqui tribe was properly consulted and that consent from the Yaqui tribe was properly received. Representatives of the Bácum community appealed this decision, causing the suspension order preventing Sempra Infrastructure from repairing the damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory to remain in place until the appeals process is exhausted. In December 2021, the court of appeals referred the matter to Mexico’s Supreme Court. In June 2022, the Supreme Court remanded the case back to the court of appeals for final resolution.

Sempra Infrastructure exercised its rights under the contract, which included seeking force majeure payments for the two-year period such force majeure payments were required to be made, which ended in August 2019.

In July 2019, the CFE filed a request for arbitration generally to nullify certain contract terms that provide for fixed capacity payments in instances of force majeure and made a demand for substantial damages in connection with the force majeure event. In September 2019, the arbitration process ended when Sempra Infrastructure and the CFE reached an agreement to restart natural gas transportation service on the earlier of completion of repair of the damaged pipeline or January 15, 2020, and to modify the tariff structure and extend the term of the contract by 10 years. Subsequently, Sempra Infrastructure and the CFE agreed to extend the service start date multiple times, most recently to November 30, 2022. Under the revised agreement, the CFE will resume making payments only when the damaged section of the Guaymas-El Oro segment of the Sonora pipeline is repaired. If the pipeline is not repaired by November 30, 2022, and 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. Discussions with the CFE regarding the future of the pipeline are underway in accordance with a non-binding MOU announced in January 2022 that, among other matters, addresses efforts to restart service on the pipeline. In July 2022, Sempra Infrastructure and the CFE entered into a Shareholders’ Agreement that establishes a framework for a JV between the parties to work on restarting service on the pipeline, including the potential re-routing of a portion of the pipeline. This agreement is subject to a number of conditions to be satisfied before it becomes effective, including regulatory and corporate authorizations.

At June 30, 2022, Sempra Infrastructure had $426 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if Sempra Infrastructure is unable to make such repairs (which have not

commenced) or re-route a portion of the pipeline (which has not been agreed to by the parties, but is subject to negotiation pursuant to a non-binding MOU and a Shareholders’ Agreement, as described above) and resume operations or if Sempra Infrastructure terminates the contract and is unable to obtain recovery, which in each case could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.Sasabe-Puerto Libertad-Guaymas Segment. In June 2014, Sempra Infrastructure and a landowner agreed to enter into a voluntary right-of-way easement agreement for the construction and operation of a seven-mile section of the 314-mile Sasabe-Puerto Libertad-Guaymas segment of the Sonora natural gas pipeline on the landowner’s property. However, in 2015, the landowner filed a complaint demanding the easement agreement be nullified. In September 2021, a definitive and non-appealable judgment was issued declaring the easement agreement nullified and ordering the removal of the pipeline from the landowner’s property. The execution of the judgment is suspended as a result of an amparo lawsuit filed by the CFE as an interested third party that did not participate in the litigation. Sempra Infrastructure filed a special judicial action asking the civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. In July 2022, Sempra Infrastructure and the landowner entered into a new easement agreement approved by the court for the seven-mile section on the landowner’s property, thus bringing this case to definitive conclusion.

Regulatory and Other Actions by the Mexican Government

We describe below certain actions by the Mexican government that could have a material impact on the energy sector in Mexico. Sempra Infrastructure and other parties affected by these resolutions, orders, decrees, regulations and proposed amendments to Mexican law have challenged them by filing amparo and other claims, some of which have been granted injunctive relief. The court-ordered injunctions or suspensions provide temporary relief until Mexico’s federal district court or Supreme Court ultimately resolves the amparo and other claims. An unfavorable decision on one or more of these amparo or other challenges or the potential for extended disputes may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, may result in decreased revenues and cash flows, and may negatively impact our ability to recover the carrying values of our investments in Mexico, any of which may have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects.

Transmission Rates for Legacy Generation Facilities. In May 2020, the CRE approved an update to the transmission rates included in legacy renewable and cogeneration energy contracts based on the claim that the legacy transmission rates did not reflect fair and proportional costs for providing the applicable services and, therefore, created inequitable competitive conditions. Three of Sempra Infrastructure’s renewable energy facilities (Don Diego Solar, Border Solar and Ventika) are currently holders of contracts with such legacy rates, and under the terms of these contracts any increases in the transmission rates would be passed through directly to their customers. These renewable energy facilities sought and obtained injunctive relief but were required to guarantee the difference in tariffs. The three facilities obtained favorable resolutions from a lower court and the CRE appealed those decisions, which were definitively affirmed in favor of the Don Diego Solar, Border Solar and Ventika facilities, whereby the injunctions were made permanent, the regulations were declared unconstitutional, and the guarantee was determined to not be required. The resolution is definitive and final.

Offtakers of Legacy Generation Permits. In October 2020, the CRE approved a resolution to amend the rules for the inclusion of new offtakers of legacy generation and self-supply permits (the Offtaker Resolution), which became effective immediately. The Offtaker Resolution prohibits self-supply permit holders from adding new offtakers that were not included in the original development or expansion plans, making modifications to the amount of energy allocated to the named offtakers, and including load centers that have entered into a supply arrangement under Mexico’s Electricity Industry Law. Don Diego Solar, Border Solar and Ventika are holders of self-supply permits and are impacted by the Offtaker Resolution. In January 2022, Don Diego Solar and Border Solar obtained a favorable resolution from a Mexican federal district court and the CRE appealed that decision. If Sempra Infrastructure is not able to obtain legal protection for these impacted facilities, Sempra Infrastructure expects it will sell Border Solar’s capacity and a portion of Don Diego Solar’s capacity affected by the Offtaker Resolution into the spot market. Currently, prices in the spot market are higher than the fixed prices in the PPAs that were entered into through self-supply permits, but these markets are subject to significant volatility. At June 30, 2022, Sempra Infrastructure had $14 million in other intangible assets, net, related to these self-supply permits previously granted by the CRE and impacted by the Offtaker Resolution that could be subject to impairment if Sempra Infrastructure is unable to obtain adequate legal protection. Sempra Infrastructure has filed lawsuits against the Offtaker Resolution and received injunctive relief pending final resolution.Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective on March 10, 2021, and SENER, the CRE and CENACE were to have 180 calendar days to modify, as necessary, all resolutions, policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. However, a Mexican court issued a suspension of the amendments on March 19, 2021. In April 2022, the Mexican Supreme Court resolved an action of unconstitutionality filed by a group of senators against the amended Electricity Industry Law, but the qualified majority of eight votes out of 11 as is required in matters involving constitutionality was not reached and the proceeding was dismissed, which means that the Mexican Supreme Court did not issue a binding precedent and the amended Electricity Industry Law remains in force. Sempra Infrastructure filed three lawsuits against the amendments to the Electricity Industry Law and, in each of them, Sempra Infrastructure obtained a favorable judgment of the first instance in the lower courts, which has been appealed. If the proposed amendments are affirmed by the lower courts or by the Mexican Supreme Court (which in these cases would only require a simple majority vote), the CRE may be required to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, under a legal standard that is ambiguous and not well defined under the law.Amendments to Mexico’s Hydrocarbons Law. In May 2021, amendments to Mexico’s Hydrocarbons Law were published and became effective. The amendments grant SENER and the CRE additional powers to suspend and revoke permits related to the midstream and downstream sectors. Suspension of permits will be determined by SENER or the CRE when a danger to national security, energy security, or to the national economy is foreseen. Likewise, new grounds for the revocation of permits are in place if the permit holder (i) carries out its activity with illegally imported products; (ii) fails, on more than one occasion, to comply with the provisions applicable to quantity, quality and measurement of the products; or (iii) modifies the technical conditions of its infrastructure without authorization. Additionally, in the case of existing permits, authorities will revoke those permits that fail to comply with the minimum storage requirements established by SENER or fail to comply with requirements or violate provisions established by the amended Hydrocarbons Law. All the Sempra Infrastructure entities participating in the Mexico hydrocarbons sector filed lawsuits against the initiative to reform the Hydrocarbons Law. In 2021, district courts issued judgments that the amendments do not affect the interests of the companies at this time and, as a result, dismissed the amparo lawsuits, including the lawsuits filed by Sempra Infrastructure entities. The Sempra Infrastructure entities have appealed these judgments. The Circuit Courts upheld the dismissal of the amparo lawsuits, except one that is pending resolution.Proposed Constitutional Reform in Mexico. In September 2021, the President of Mexico presented a constitutional reform initiative with the stated goal of preserving energy security and self-sufficiency, and a continuous supply of electricity to the country’s population, as a condition for guaranteeing national security and the human right to a decent life. The CRE and the National Commission of Hydrocarbons would be dissolved, and their functions would be carried out by SENER. CENACE would be reinstated to the CFE, and the CFE would be responsible for generating, conducting, transforming, distributing and supplying electricity, and would be the only entity allowed to commercialize electric energy in Mexico. Electricity generation permits and contracts for the sale of electricity and RECs to the CFE, including permits at all of Sempra Infrastructure’s operational power generation facilities, would be canceled. The public electricity supply service would be provided exclusively by the CFE, which may acquire up to 46% of required energy from the private sector. Only certain private power plants would be permitted to continue generating electricity and compete to offer the CFE the lowest production costs. On April 17, 2022, the Chamber of Deputies in Mexico rejected the proposed constitutional reform.

Other Litigation

RBS Sempra Commodities

Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In 2015, liquidators filed a claim in the High Court of Justice against RBS (now NatWest Markets plc, our partner in the JV) and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE, a subsidiary of RBS Sempra Commodities. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million (approximately $55 million in U.S. dollars at June 30, 2022), 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 June 30, 2022) 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.

In the second quarter of 2021, we reduced our estimate of our obligations to settle pending VAT matters and related legal costs by $50 million in Equity Earnings on Sempra’s Condensed Consolidated Statement of Operations based on the settlement with Her Majesty’s Revenue and Customs (U.K.’s Revenue and Customs Department) on the First-Tier Tribunal case and revised assumptions on the High Court of Justice case.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of August 1, 2022, one lawsuit is pending. Additionally, in connection with the EFH bankruptcy proceeding, approximately 28,000 proofs of claim were filed on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding. The costs to defend or resolve these lawsuits and the amount of damages that may be imposed or incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Ordinary Course Litigation

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

LEASES

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

Lessee Accounting

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

Leases That Have Not Yet Commenced

SDG&E has entered into three energy storage tolling agreements, of which SDG&E expects two will commence in the third quarter of 2022 and one will commence in the second quarter of 2023. SDG&E expects the future minimum lease payments to be $7 million in 2022, $18 million in each of 2023 through 2026 and $101 million thereafter until expiration at various dates from 2032 through 2033.

SoCalGas has entered into a fleet vehicle agreement, under which SoCalGas expects leases will commence in the second half of 2022 through the first half of 2023. SoCalGas expects the future minimum lease payments to be $2 million in each of 2023 through 2026 and $10 million thereafter until expiration at various dates from 2030 through 2031.

Lessor Accounting

Sempra Infrastructure is a lessor for certain of its natural gas and ethane pipelines, compressor stations, liquid petroleum gas storage facilities, a rail facility and liquid fuels 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 June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sales-type leases:
Interest income	$	2	$	—	$	4	$	—
Total revenues from sales-type leases(1)	$	2	$	—	$	4	$	—
Operating leases:
Fixed lease payments	$	70	$	59	$	140	$	112
Variable lease payments	3		1		4		1
Total revenues from operating leases(1)	$	73	$	60	$	144	$	113
Depreciation expense	$	14	$	12	$	27	$	22

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

CONTRACTUAL COMMITMENTS

We discuss below significant changes in the first six months of 2022 to contractual commitments discussed in Notes 1 and 16 of the Notes to Consolidated Financial Statements in the Annual Report.

LNG Purchase Agreement

Sempra Infrastructure has a 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 2022 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the supplier may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure. At June 30, 2022, we expect the commitment amount to decrease by $208 million in 2022 and then increase by $227 million in 2023, $203 million in 2024, $191 million in 2025, $175 million in 2026 and by $421 million thereafter (through contract termination in 2029) compared to December 31, 2021, reflecting changes in estimated forward prices since December 31, 2021 and actual transactions for the first six months of 2022. These LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted, under the agreement are delivered. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amount provided under the agreement due to the customer electing to divert cargoes as allowed by the agreement.

ENVIRONMENTAL ISSUES

We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $59 million for Sempra, $18 million for SDG&E and $15 million for SoCalGas at June 30, 2022.

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SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

SEGMENT INFORMATION

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 electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, 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. Sempra Infrastructure owns a 70% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at June 30, 2022.

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

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

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

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
REVENUES
SDG&E	$	1,399	$	1,318	$	2,844	$	2,655
SoCalGas	1,501		1,124		3,494		2,632
Sempra Infrastructure	689		341		1,113		790
All other	—		1		—		2
Adjustments and eliminations	(2)		(1)		—		(1)
Intersegment revenues(1)	(40)		(42)		(84)		(78)
Total	$	3,547	$	2,741	$	7,367	$	6,000
DEPRECIATION AND AMORTIZATION
SDG&E	$	244	$	220	$	483	$	433
SoCalGas	188		180		375		353
Sempra Infrastructure	67		59		132		113
All other	2		4		4		6
Total	$	501	$	463	$	994	$	905
INTEREST INCOME
SDG&E	$	1	$	—	$	1	$	1
SoCalGas	1		—		1		—
Sempra Infrastructure	9		20		30		41
All other	4		1		8		1
Intercompany eliminations	—		(6)		—		(9)
Total	$	15	$	15	$	40	$	34
INTEREST EXPENSE
SDG&E	$	114	$	101	$	220	$	203
SoCalGas	45		40		85		79
Sempra Infrastructure	32		45		59		86
All other	81		79		151		162
Intercompany eliminations	(1)		(7)		(1)		(13)
Total	$	271	$	258	$	514	$	517
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	42	$	33	$	106	$	78
SoCalGas	19		8		103		102
Sempra Infrastructure	70		94		161		151
All other	(51)		4		44		(34)
Total	$	80	$	139	$	414	$	297
EQUITY EARNINGS (LOSSES)
Equity earnings, before income tax:
Sempra Texas Utilities	$	3	$	2	$	5	$	3
Sempra Infrastructure	156		133		297		267
All other	—		50		—		50
	159		185		302		320
Equity earnings (losses), net of income tax:
Sempra Texas Utilities	184		137		346		273
Sempra Infrastructure	32		(9)		53		38
	216		128		399		311
Total	$	375	$	313	$	701	$	631

(1)    Revenues for reportable segments include intersegment revenues of $3, $23, and $14 for the three months ended June 30, 2022; $7, $49, and $28 for the six months ended June 30, 2022; $2, $23, and $17 for the three months ended June 30, 2021 and $4, $48, and $26 for the six months ended June 30, 2021 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176	$	186	$	410	$	398
SoCalGas	87		94		421		501
Sempra Texas Utilities	186		138		348		273
Sempra Infrastructure	183		53		278		255
All other	(73)		(47)		(286)		(129)
Total	$	559	$	424	$	1,171	$	1,298
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,090	$	1,072
SoCalGas					931		936
Sempra Infrastructure					336		415
All other					4		1
Total					$	2,361	$	2,424
					June 30, 2022		December 31, 2021
ASSETS
SDG&E					$	25,075	$	24,058
SoCalGas					21,354		20,324
Sempra Texas Utilities					13,406		13,047
Sempra Infrastructure					14,958		14,408
All other					1,984		1,399
Intersegment receivables					(1,195)		(1,191)
Total					$	75,582	$	72,045
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	13,406	$	13,047
Sempra Infrastructure					1,687		1,425
Total					$	15,093	$	14,472

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GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Principles of Consolidation

PRINCIPLES OF CONSOLIDATION

Sempra

Sempra’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, which resulted in a change to our reportable segments. Historical segment disclosures have been restated to conform with the current presentation of our four separate reportable segments, which we discuss in Note 12. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name.

SDG&E

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

SoCalGas

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

Basis of Presentation

BASIS OF PRESENTATION

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

We have prepared our Condensed Consolidated Financial Statements in conformity with U.S. GAAP and in accordance with the interim period reporting requirements of Form 10-Q and applicable rules of the SEC. The financial statements reflect all adjustments that are necessary for a fair presentation of the results for the interim periods. These adjustments are only of a normal, recurring nature. Results of operations for interim periods are not necessarily indicative of results for the entire year or for any other period. We evaluated events and transactions that occurred after June 30, 2022 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, 2021 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2021 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim period reporting provisions of U.S. GAAP and the SEC.

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

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

Regulated Operations

Regulated Operations

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

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

Our Sempra Infrastructure segment includes the operating companies of our subsidiary, IEnova, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity.

Credit Losses

We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in sales-type leases and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 6.

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

Variable Interest Entity Policy

VARIABLE INTEREST ENTITIES

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

▪the purpose and design of the VIE;

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

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

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

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

Earnings Per Share Policy

Basic EPS is calculated by dividing earnings attributable to common shares by the weighted-average number of common shares outstanding for the period. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect.In 2021, the potentially dilutive impact from mandatory convertible preferred stock was calculated under the if-converted method until the mandatory conversion date. After the mandatory conversion date, the converted shares are included in weighted-average common shares outstanding for basic EPS.

Interim period effective tax rate policy

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

Flow-through rate-making treatment tax policy

For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense or benefit, 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

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

New Accounting Standards

ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We adopted the standard on January 1, 2022 using a modified retrospective approach and the adoption did not materially impact our financial statements or per-share amounts.

Derivative Financial Instruments

HEDGE ACCOUNTING

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

ENERGY DERIVATIVES

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

▪SDG&E and SoCalGas use natural gas derivatives and SDG&E uses electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, 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 that have been filed with and approved by the CPUC. 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 Electric Fuel and Purchased Power or in Cost of Natural Gas.

▪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 their assets which support the following businesses: LNG, natural gas transportation 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. Certain of these derivatives may also be designated as cash flow hedges.

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

INTEREST RATE DERIVATIVES

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

FOREIGN CURRENCY DERIVATIVES

We 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.

Fair Value Measurement Policy

We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2021.

The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 8 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 derivatives 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 6, 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.”

The impact associated with discounting is negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a significantly higher (lower) fair value measurement. We summarize CRR volumes in Note 8.

A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 8.

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

Fair Value of Financial InstrumentsThe fair values of certain of our financial instruments (cash, accounts receivable, amounts due to/from unconsolidated affiliates with original maturities of less than 90 days, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts.

Legal Costs Policy

LEGAL PROCEEDINGS

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

Gains and Losses on NDTs

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

Segment Information

We have four separately managed reportable segments, as follows:

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

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

▪Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings L.P., which owns Sharyland Utilities, 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. Sempra Infrastructure owns a 70% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at June 30, 2022.

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.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash and Cash Equivalents

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

RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	June 30, 2022		December 31, 2021
Cash and cash equivalents	$	1,931	$	559
Restricted cash, current	103		19
Restricted cash, noncurrent	59		3
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$	2,093	$	581

Accounts Receivable, Allowance for Credit Loss Table

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

RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	2022		2021
Sempra:
Allowances for credit losses at January 1	$	136	$	138
Provisions for expected credit losses	77		66
Write-offs	(36)		(12)
Allowances for credit losses at June 30	$	177	$	192
SDG&E:
Allowances for credit losses at January 1	$	66	$	69
Provisions for expected credit losses	37		13
Write-offs	(18)		(7)
Allowances for credit losses at June 30	$	85	$	75
SoCalGas:
Allowances for credit losses at January 1	$	69	$	68
Provisions for expected credit losses	37		52
Write-offs	(18)		(5)
Allowances for credit losses at June 30	$	88	$	115

Allowances for credit losses related to accounts receivable are included in the Condensed Consolidated Balance Sheets as follows:

ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	June 30,		December 31,
	2022		2021
Sempra:
Accounts receivable – trade, net	$	142	$	94
Accounts receivable – other, net	33		39
Other long-term assets	2		3
Total allowances for credit losses	$	177	$	136
SDG&E:
Accounts receivable – trade, net	$	62	$	42
Accounts receivable – other, net	22		22
Other long-term assets	1		2
Total allowances for credit losses	$	85	$	66
SoCalGas:
Accounts receivable – trade, net	$	76	$	51
Accounts receivable – other, net	11		17
Other long-term assets	1		1
Total allowances for credit losses	$	88	$	69

Inventory Table

The components of inventories are as follows:

INVENTORY BALANCES
(Dollars in millions)
	Sempra				SDG&E				SoCalGas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Natural gas	$	138	$	164	$	—	$	—	$	102	$	114
LNG	31		27		—		—		—		—
Materials and supplies	208		198		124		123		67		58
Total	$	377	$	389	$	124	$	123	$	169	$	172

Capitalized Financing Costs Table

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

CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra	$	60	$	55	$	117	$	114
SDG&E	26		28		54		58
SoCalGas	17		15		35		31

Net Periodic Benefit Cost Table

The following three 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 (Expense) Income, Net, table below.

NET PERIODIC BENEFIT COST – SEMPRA
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	42	$	36	$	6	$	5
Interest cost	29		28		7		7
Expected return on assets	(45)		(43)		(16)		(15)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	5		11		(3)		(2)
Net periodic benefit cost (credit)	33		34		(6)		(5)
Regulatory adjustments	24		22		6		5
Total expense recognized	$	57	$	56	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	83	$	73	$	13	$	11
Interest cost	59		56		14		14
Expected return on assets	(91)		(86)		(32)		(30)
Amortization of:
Prior service cost (credit)	5		5		(1)		(1)
Actuarial loss (gain)	11		22		(7)		(4)
Settlement charges	—		7		—		—
Net periodic benefit cost (credit)	67		77		(13)		(10)
Regulatory adjustments	(3)		(7)		13		10
Total expense recognized	$	64	$	70	$	—	$	—

NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	10	$	9	$	1	$	1
Interest cost	6		6		2		2
Expected return on assets	(11)		(13)		(3)		(3)
Amortization of:
Actuarial loss (gain)	1		1		—		(1)
Net periodic benefit cost (credit)	6		3		—		(1)
Regulatory adjustments	7		11		—		1
Total expense recognized	$	13	$	14	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	20	$	17	$	3	$	2
Interest cost	13		12		3		3
Expected return on assets	(22)		(25)		(5)		(5)
Amortization of:
Actuarial loss (gain)	1		1		(1)		(1)
Net periodic benefit cost (credit)	12		5		—		(1)
Regulatory adjustments	2		9		—		1
Total expense recognized	$	14	$	14	$	—	$	—

NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended June 30,
	2022		2021		2022		2021
Service cost	$	28	$	25	$	5	$	4
Interest cost	21		20		6		6
Expected return on assets	(33)		(30)		(14)		(12)
Amortization of:
Prior service cost	2		2		—		—
Actuarial loss (gain)	4		10		(3)		(2)
Net periodic benefit cost (credit)	22		27		(6)		(4)
Regulatory adjustments	17		11		6		4
Total expense recognized	$	39	$	38	$	—	$	—
	Six months ended June 30,
	2022		2021		2022		2021
Service cost	$	56	$	50	$	10	$	8
Interest cost	41		40		11		11
Expected return on assets	(64)		(58)		(27)		(24)
Amortization of:
Prior service cost (credit)	4		4		(1)		(1)
Actuarial loss (gain)	8		19		(6)		(3)
Net periodic benefit cost (credit)	45		55		(13)		(9)
Regulatory adjustments	(5)		(16)		13		9
Total expense recognized	$	40	$	39	$	—	$	—

Earnings Per Share Computations Table

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

EARNINGS PER COMMON SHARE COMPUTATIONS
(Dollars in millions, except per share amounts; shares in thousands)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Numerator:
Earnings attributable to common shares	$	559	$	424	$	1,171	$	1,298
Denominator:
Weighted-average common shares outstanding for basic EPS(1)	314,845		307,800		315,595		304,372
Dilutive effect of stock options and RSUs(2)	1,022		807		1,052		846
Dilutive effect of mandatory convertible preferred stock	—		—		—		1,066
Weighted-average common shares outstanding for diluted EPS	315,867		308,607		316,647		306,284
EPS:
Basic	$	1.78	$	1.38	$	3.71	$	4.27
Diluted	$	1.77	$	1.37	$	3.70	$	4.24

(1)    Includes 399 and 447 fully vested RSUs held in our Deferred Compensation Plan for the three months ended June 30, 2022 and 2021, respectively, and 403 and 454 of such RSUs for the six months ended June 30, 2022 and 2021, 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.

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 other postretirement benefits		Total accumulated other comprehensive income (loss)
	Three months ended June 30, 2022 and 2021
Sempra:
Balance at March 31, 2022	$	(76)	$	(78)	$	(75)	$	(229)
OCI before reclassifications	1		37		1		39
Amounts reclassified from AOCI(2)	10		11		2		23
Net OCI(2)	11		48		3		62
Balance at June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance at March 31, 2021	$	(69)	$	(239)	$	(91)	$	(399)
OCI before reclassifications(3)	(19)		(36)		(2)		(57)
Amounts reclassified from AOCI	—		10		2		12
Net OCI(3)	(19)		(26)		—		(45)
Balance at June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at March 31, 2022 and June 30, 2022					$	(10)	$	(10)
Balance at March 31, 2021 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance at March 31, 2022			$	(13)	$	(17)	$	(30)
Amounts reclassified from AOCI			1		—		1
Net OCI			1		—		1
Balance at June 30, 2022			$	(12)	$	(17)	$	(29)
Balance at March 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance at June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, 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 other postretirement benefits		Total accumulated other comprehensive income (loss)
	Six months ended June 30, 2022 and 2021
Sempra:
Balance as of December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
OCI before reclassifications	4		111		7		122
Amounts reclassified from AOCI(2)	10		15		4		29
Net OCI(2)	14		126		11		151
Balance as of June 30, 2022	$	(65)	$	(30)	$	(72)	$	(167)
Balance as of December 31, 2020	$	(64)	$	(331)	$	(105)	$	(500)
OCI before reclassifications(3)	(24)		37		5		18
Amounts reclassified from AOCI	—		29		9		38
Net OCI(3)	(24)		66		14		56
Balance as of June 30, 2021	$	(88)	$	(265)	$	(91)	$	(444)
SDG&E:
Balance at December 31, 2021 and June 30, 2022					$	(10)	$	(10)
Balance at December 31, 2020 and June 30, 2021					$	(10)	$	(10)
SoCalGas:
Balance as of December 31, 2021			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			1		1		2
Net OCI			1		1		2
Balance as of June 30, 2022			$	(12)	$	(17)	$	(29)
Balance as of December 31, 2020			$	(13)	$	(18)	$	(31)
Amounts reclassified from AOCI			—		1		1
Net OCI			—		1		1
Balance as of June 30, 2021			$	(13)	$	(17)	$	(30)

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

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

(3)    Total AOCI includes $24 of foreign currency translation adjustments and $14 of financial instruments associated with the IEnova exchange offer, 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 AOCI Table

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Three months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	—	$	(1)	Interest Expense
Interest rate instruments	13		19		Equity Earnings(1)
Foreign exchange instruments	(1)		—		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	—		(7)		Other (Expense) Income, Net
Total, before income tax	12		11
	(4)		(1)		Income Tax Expense
Total, net of income tax	8		10
	3		—		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	11	$	10
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	2	$	1	Other (Expense) Income, Net
Amortization of prior service cost	1		1		Other (Expense) Income, Net
Total, before income tax	3		2
	(1)		—		Income Tax Expense
Total, net of income tax	$	2	$	2
Total reclassifications for the period, net of income  tax and NCI	$	14	$	12
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of prior service cost	$	—	$	1	Other Income (Expense), Net
Total reclassifications for the period, net of income  tax	$	1	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (CONTINUED)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)				Affected line item on Condensed Consolidated Statements of Operations
	Six months ended June 30,
	2022		2021
Sempra:
Foreign currency translation adjustments	$	1	$	—	Operation and Maintenance
Financial instruments:
Interest rate instruments	$	(1)	$	1	Interest Expense
Interest rate instruments	27		38		Equity Earnings(1)
Foreign exchange instruments	(2)		1		Revenues: Energy-Related Businesses
	1		—		Other (Expense) Income, Net
Foreign exchange instruments	(1)		1		Equity Earnings(1)
Interest rate and foreign exchange instruments	(1)		—		Interest Expense
	(6)		(1)		Other (Expense) Income, Net
Total, before income tax	17		40
	(5)		(9)		Income Tax Expense
Total, net of income tax	12		31
	3		(2)		Earnings Attributable to Noncontrolling Interests
Total, net of income tax and after NCI	$	15	$	29
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	4	$	3	Other (Expense) Income, Net
Amortization of prior service cost	2		2		Other (Expense) Income, Net
Settlement charges	—		7		Other (Expense) Income, Net
Total, before income tax	6		12
	(2)		(3)		Income Tax Expense
Total, net of income tax	$	4	$	9
Total reclassifications for the period, net of income  tax and NCI	$	20	$	38
SoCalGas:
Financial instruments:
Interest rate instruments	$	1	$	—	Interest Expense
Pension and other postretirement benefits(2):
Amortization of actuarial loss	$	1	$	—	Other Income (Expense), Net
Amortization of prior service cost	—		1		Other Income (Expense), Net
Total, before income tax	1		1
	—		—		Income Tax Expense
Total, net of income tax	$	1	$	1
Total reclassifications for the period, net of income  tax	$	2	$	1

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

(2)    Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).

Ownership Interests Held By Others Table

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

OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests				Equity held by noncontrolling interests
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Sempra Infrastructure:
SI Partners	30.0	%	20.0	%	$	2,146	$	1,384
SI Partners subsidiaries(1)	0.1 - 16.6		0.1 - 16.6		46		34
Total Sempra					$	2,192	$	1,418

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

Transactions with Affiliates Table

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

AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Sempra Infrastructure – IMG – Note due March 15, 2023(1)	$	626	$	2
Various affiliates	20		21
Total due from unconsolidated affiliates – current	$	646	$	23
Sempra Infrastructure – IMG – Note due March 15, 2022, net of allowance for credit losses of $1 at December 31, 2021(1)	$	—	$	637
Total due from unconsolidated affiliates – noncurrent	$	—	$	637
Sempra Infrastructure(2):
TAG Pipelines Norte, S. de R.L. de C.V.:
5.5% Note due January 9, 2024	$	(39)	$	(69)
5.5% Note due January 14, 2025	(22)		(21)
5.5% Note due July 16, 2025	(21)		(20)
5.5% Note due January 14, 2026	(18)		—
TAG – 5.74% Note due December 17, 2029	(182)		(177)
Total due to unconsolidated affiliates – noncurrent	$	(282)	$	(287)
SDG&E:
Sempra	$	(26)	$	(40)
SoCalGas	(30)		(48)
Various affiliates	(12)		(9)
Total due to unconsolidated affiliates – current	$	(68)	$	(97)
Income taxes due from Sempra(3)	$	21	$	19
SoCalGas:
SDG&E	$	30	$	48
Various affiliates	1		1
Total due from unconsolidated affiliates – current	$	31	$	49
Sempra	$	(36)	$	(36)
Total due to unconsolidated affiliates – current	$	(36)	$	(36)
Income taxes due from Sempra(3)	$	6	$	6

(1)    At December 31, 2021, represents a Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $691 U.S. dollar-equivalent at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps. In March 2022, Sempra Infrastructure amended and restated the revolving line of credit to a U.S. dollar-denominated note in the amount of $625 at a variable interest rate based on the adjusted 1-month Secured Overnight Financing Rate plus 180 bps (3.41% at June 30, 2022) and extended the maturity date to March 15, 2023. At June 30, 2022 and December 31, 2021, $1 and $2 of accrued interest receivable, respectively, is included in Due from Unconsolidated Affiliates – Current. In July 2022, this note receivable was paid in full.

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

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

The following table summarizes income statement information from unconsolidated affiliates.

INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Revenues	$	15	$	7	$	22	$	15
Cost of sales	—		—		—		11
Interest income	4		12		14		27
Interest expense	4		3		8		7
SDG&E:
Revenues	$	4	$	2	$	8	$	4
Cost of sales	26		27		50		55
SoCalGas:
Revenues	$	23	$	23	$	49	$	48
Cost of sales(1)	(4)		—		(4)		3

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

Other Income and Expense Table

Other (expense) income, net, consists of the following:

OTHER (EXPENSE) INCOME, NET
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sempra:
Allowance for equity funds used during construction	$	34	$	34	$	69	$	72
Investment (losses) gains, net(1)	(34)		19		(47)		28
(Losses) gains on interest rate and foreign exchange instruments, net	(1)		7		5		(23)
Foreign currency transaction (losses) gains, net(2)	(3)		26		(22)		7
Non-service components of net periodic benefit (cost) credit	(9)		(15)		32		14
Interest on regulatory balancing accounts, net	4		2		5		3
Sundry, net	8		(1)		(5)		6
Total	$	(1)	$	72	$	37	$	107
SDG&E:
Allowance for equity funds used during construction	$	21	$	22	$	42	$	45
Non-service components of net periodic benefit (cost) credit	(2)		(4)		9		5
Interest on regulatory balancing accounts, net	3		2		4		3
Sundry, net	—		2		1		4
Total	$	22	$	22	$	56	$	57
SoCalGas:
Allowance for equity funds used during construction	$	13	$	11	$	26	$	23
Non-service components of net periodic benefit (cost) credit	(6)		(9)		26		19
Interest on regulatory balancing accounts, net	1		—		1		—
Sundry, net	(4)		(4)		(15)		(5)
Total	$	4	$	(2)	$	38	$	37

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

(2)    Includes losses of $11 in the six months ended June 30, 2022 and gains of $28 and $5 in the three months and six months ended June 30, 2021, respectively, 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 Statements of Operations.

Income Tax Expense and Effective Income Tax Rates Table

We provide our calculations of ETRs in the following table.

INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Three months ended June 30,						Six months ended June 30,
	2022			2021			2022			2021
Sempra:
Income tax expense	$	80		$	139		$	414		$	297
Income before income taxes and equity earnings	$	364		$	281		$	1,029		$	1,049
Equity earnings, before income tax(1)	159			185			302			320
Pretax income	$	523		$	466		$	1,331		$	1,369
Effective income tax rate	15		%	30		%	31		%	22		%
SDG&E:
Income tax expense	$	42		$	33		$	106		$	78
Income before income taxes	$	218		$	219		$	516		$	476
Effective income tax rate	19		%	15		%	21		%	16		%
SoCalGas:
Income tax expense	$	19		$	8		$	103		$	102
Income before income taxes	$	107		$	103		$	525		$	604
Effective income tax rate	18		%	8		%	20		%	17		%

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

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REVENUES (Tables)

6 Months Ended

Jun. 30, 2022

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 June 30, 2022
By major service line:
Utilities	$	1,250	$	1,347	$	20	$	(27)	$	2,590
Energy-related businesses	—		—		457		(14)		443
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
By market:
Gas	$	159	$	1,347	$	340	$	(19)	$	1,827
Electric	1,091		—		137		(22)		1,206
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Revenues from contracts with customers	$	1,250	$	1,347	$	477	$	(41)	$	3,033
Utilities regulatory revenues	149		154		—		—		303
Other revenues	—		—		212		(1)		211
Total revenues	$	1,399	$	1,501	$	689	$	(42)	$	3,547
	Six months ended June 30, 2022
By major service line:
Utilities	$	2,751	$	3,259	$	48	$	(56)	$	6,002
Energy-related businesses	—		—		749		(29)		720
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
By market:
Gas	$	489	$	3,259	$	569	$	(45)	$	4,272
Electric	2,262		—		228		(40)		2,450
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Revenues from contracts with customers	$	2,751	$	3,259	$	797	$	(85)	$	6,722
Utilities regulatory revenues	93		235		—		—		328
Other revenues	—		—		316		1		317
Total revenues	$	2,844	$	3,494	$	1,113	$	(84)	$	7,367

DISAGGREGATED REVENUES (CONTINUED)
(Dollars in millions)
	SDG&E		SoCalGas		Sempra Infrastructure		Consolidating adjustments and Parent and other		Sempra
	Three months ended June 30, 2021
By major service line:
Utilities	$	1,170	$	1,062	$	17	$	(25)	$	2,224
Energy-related businesses	—		—		260		(14)		246
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
By market:
Gas	$	162	$	1,062	$	185	$	(24)	$	1,385
Electric	1,008		—		92		(15)		1,085
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Revenues from contracts with customers	$	1,170	$	1,062	$	277	$	(39)	$	2,470
Utilities regulatory revenues	148		62		—		—		210
Other revenues	—		—		64		(3)		61
Total revenues	$	1,318	$	1,124	$	341	$	(42)	$	2,741
	Six months ended June 30, 2021
By major service line:
Utilities	$	2,386	$	2,719	$	44	$	(52)	$	5,097
Energy-related businesses	—		—		529		(15)		514
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
By market:
Gas	$	435	$	2,719	$	397	$	(48)	$	3,503
Electric	1,951		—		176		(19)		2,108
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Revenues from contracts with customers	$	2,386	$	2,719	$	573	$	(67)	$	5,611
Utilities regulatory revenues	269		(87)		—		—		182
Other revenues	—		—		217		(10)		207
Total revenues	$	2,655	$	2,632	$	790	$	(77)	$	6,000

Schedule of Timing of Remaining Performance Obligations

For contracts greater than one year, at June 30, 2022, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure and transmission line projects at SDG&E. SoCalGas did not have any remaining performance obligations at June 30, 2022.

REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2022 (excluding first six months of 2022)	$	200	$	2
2023	384		4
2024	385		4
2025	384		4
2026	382		4
Thereafter	4,525		63
Total revenues to be recognized	$	6,260	$	81

(1)    Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in the six months ended June 30, 2022 or 2021. As we discuss in Note 11, Sempra Infrastructure drew against and fully exhausted Gazprom’s letters of credit in April 2022 due to Gazprom’s non-renewal of such letters of credit as required under its LNG storage and regasification agreement. Sempra Infrastructure recorded a contract liability for the funds drawn from the letters of credit as payments received in advance. Gazprom has not paid its invoices since March 2022, so funds drawn from the letters of credit have been used to fully offset such nonpayment, which have been reflected as revenue from performance obligations satisfied during the reporting period. We expect that these funds will provide payment security from Gazprom through the end of 2024.

CONTRACT LIABILITIES
(Dollars in millions)
	2022		2021
Sempra:
Contract liabilities at January 1	$	(278)	$	(207)
Revenue from performance obligations satisfied during reporting period	86		49
Payments received in advance	(105)		(1)
Contract liabilities at June 30(1)	$	(297)	$	(159)
SDG&E:
Contract liabilities at January 1	$	(83)	$	(87)
Revenue from performance obligations satisfied during reporting period	2		2
Contract liabilities at June 30(1)	$	(81)	$	(85)

(1)     Balances at June 30, 2022 include $81 and $4 in Other Current Liabilities and $216 and $77 in Deferred Credits and Other on Sempra’s and SDG&E’s Condensed Consolidated Balance Sheets, respectively.

Schedule of Contract Accounts Receivable

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

RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS
(Dollars in millions)
	June 30, 2022		December 31, 2021
Sempra:
Accounts receivable – trade, net	$	1,620	$	1,886
Accounts receivable – other, net	13		19
Due from unconsolidated affiliates – current(1)	5		2
Other long-term assets(2)	32		70
Total	$	1,670	$	1,977
SDG&E:
Accounts receivable – trade, net	$	685	$	715
Accounts receivable – other, net	11		9
Due from unconsolidated affiliates – current(1)	3		2
Other long-term assets(2)	17		25
Total	$	716	$	751
SoCalGas:
Accounts receivable – trade, net	$	722	$	1,084
Accounts receivable – other, net	2		10
Other long-term assets(2)	15		45
Total	$	739	$	1,139

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

(2)     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.

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REGULATORY MATTERS (Tables)

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

Schedule of Regulatory Assets

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2022		December 31, 2021
SDG&E:
Fixed-price contracts and other derivatives	$	(24)	$	(50)
Deferred income taxes recoverable in rates	176		125
Pension and other postretirement benefit plan obligations	(8)		(7)
Removal obligations	(2,185)		(2,251)
Environmental costs	61		62
Sunrise Powerlink fire mitigation	121		122
Regulatory balancing accounts(1)(2)
Commodity – electric	246		77
Gas transportation	33		49
Safety and reliability	80		67
Public purpose programs	(117)		(107)
Wildfire mitigation plan	255		178
Liability insurance premium	102		110
Other balancing accounts	(17)		207
Other regulatory assets, net(2)	132		119
Total SDG&E	(1,145)		(1,299)
SoCalGas:
Deferred income taxes recoverable in rates	113		44
Pension and other postretirement benefit plan obligations	39		51
Employee benefit costs	31		31
Removal obligations	(603)		(627)
Environmental costs	34		34
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(46)		(146)
Safety and reliability	425		339
Public purpose programs	(213)		(183)
Liability insurance premium	18		16
Other balancing accounts	125		42
Other regulatory assets, net(2)	153		142
Total SoCalGas	76		(257)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		77
Total Sempra	$	(992)	$	(1,479)

(1)    At June 30, 2022 and December 31, 2021, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $453 and $358, respectively, and for SoCalGas was $601 and $410, respectively.

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

Schedule of Regulatory Liabilities

REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	June 30, 2022		December 31, 2021
SDG&E:
Fixed-price contracts and other derivatives	$	(24)	$	(50)
Deferred income taxes recoverable in rates	176		125
Pension and other postretirement benefit plan obligations	(8)		(7)
Removal obligations	(2,185)		(2,251)
Environmental costs	61		62
Sunrise Powerlink fire mitigation	121		122
Regulatory balancing accounts(1)(2)
Commodity – electric	246		77
Gas transportation	33		49
Safety and reliability	80		67
Public purpose programs	(117)		(107)
Wildfire mitigation plan	255		178
Liability insurance premium	102		110
Other balancing accounts	(17)		207
Other regulatory assets, net(2)	132		119
Total SDG&E	(1,145)		(1,299)
SoCalGas:
Deferred income taxes recoverable in rates	113		44
Pension and other postretirement benefit plan obligations	39		51
Employee benefit costs	31		31
Removal obligations	(603)		(627)
Environmental costs	34		34
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(46)		(146)
Safety and reliability	425		339
Public purpose programs	(213)		(183)
Liability insurance premium	18		16
Other balancing accounts	125		42
Other regulatory assets, net(2)	153		142
Total SoCalGas	76		(257)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		77
Total Sempra	$	(992)	$	(1,479)

(1)    At June 30, 2022 and December 31, 2021, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $453 and $358, respectively, and for SoCalGas was $601 and $410, respectively.

(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

In December 2019, the CPUC approved the cost of capital (shown in the table below) for SDG&E and SoCalGas that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029% based on Moody’s A- utility bond index.

AUTHORIZED CPUC COST OF CAPITAL, SUBJECT TO THE CCM
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	%	4.59	%	2.08	%	Long-Term Debt	45.60	%	4.23	%	1.93	%
2.75		6.22		0.17		Preferred Equity	2.40		6.00		0.14
52.00		10.20		5.30		Common Equity	52.00		10.05		5.23
100.00	%			7.55	%		100.00	%			7.30	%

In April 2022, SDG&E and SoCalGas each filed applications with the CPUC to update their cost of capital (shown in the table below), which would become effective on January 1, 2023 and would remain in effect through December 31, 2025, subject to the CCM if it remains in place as proposed. SDG&E and SoCalGas expect to receive a final decision by the end of 2022.

PROPOSED CPUC COST OF CAPITAL
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
46.00	%	3.87	%	1.78	%	Long-Term Debt	45.60	%	3.89	%	1.77	%
—		—		—		Preferred Equity	0.40		6.00		0.02
54.00		10.55		5.70		Common Equity	54.00		10.75		5.81
100.00	%			7.48	%		100.00	%			7.60	%

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INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)

6 Months Ended

Jun. 30, 2022

Investments [Abstract]

Condensed Financial Statements

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

SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Operating revenues	$	1,293	$	1,147	$	2,542	$	2,286
Operating expenses	(908)		(836)		(1,805)		(1,665)
Income from operations	385		311		737		621
Interest expense	(108)		(102)		(216)		(204)
Income tax expense	(52)		(34)		(94)		(70)
Net income	226		167		417		332
Noncontrolling interest held by Texas Transmission Investment LLC	(46)		(34)		(84)		(67)
Earnings attributable to Sempra(1)	180		133		333		265

(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.

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DEBT AND CREDIT FACILITIES (Tables)

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

COMMITTED LINES OF CREDIT
(Dollars in millions)
		June 30, 2022
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	May 2024	$	3,185	$	(42)	$	—	$	3,143
Sempra	May 2024	1,250		—		—		1,250
SDG&E	May 2024	1,500		—		—		1,500
SoCalGas	May 2024	750		—		—		750
SI Partners	November 2024	1,000		—		(285)		715
IEnova	September 2023	350		—		(310)		40
IEnova	February 2024	1,500		—		—		1,500
Total		$	9,535	$	(42)	$	(595)	$	8,898

FOREIGN UNCOMMITTED LINES OF CREDIT
(Dollars and U.S. dollar equivalent in millions)
			June 30, 2022
Borrower	Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
IEnova	September 2022	U.S. dollars	$	250	$	(250)	$	—
ECA LNG Phase 1(1)	August 2023	U.S. dollars or Mexican pesos	200		(32)		168
IEnova(2)	October 2023	U.S. dollars	100		(36)		64
IEnova	October 2023	U.S. dollars or Mexican pesos	20		—		20
Total			$	570	$	(318)	$	252

(1)    In March 2022, the facility was amended to increase the borrowing capacity from $100 to $200.

(2)    Advances are due in full within 180 days of the disbursement date, which may be extended in increments of 180 days provided that no advance may have a maturity date that falls more than three years after the date of disbursement.

UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		June 30, 2022
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2023 to May 2023	$	15
SoCalGas	November 2022 to October 2023	20
Sempra Infrastructure	July 2022 to October 2043	525
Parent and other	September 2022 to June 2023	170
Total		$	730

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

WEIGHTED-AVERAGE INTEREST RATES
	June 30, 2022		December 31, 2021
Sempra	2.70	%	0.60	%
SDG&E	—		0.65
SoCalGas	—		0.21

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DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2022

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	June 30, 2022	December 31, 2021
Sempra:
Natural gas	MMBtu	193	184
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SDG&E:
Natural gas	MMBtu	10	7
Electricity	MWh	—	1
Congestion revenue rights	MWh	49	45
SoCalGas:
Natural gas	MMBtu	141	201

Notional Amounts of Derivatives Table

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

INTEREST RATE DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	436	2022-2034	$	462	2022-2034

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

FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	June 30, 2022			December 31, 2021
	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2022-2023	$	306	2022-2023
Other foreign currency derivatives	65		2022-2023	106		2022-2023

Derivative Instruments on the Condensed Consolidated Balance Sheets Table

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	June 30, 2022
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	5	$	27	$	—	$	—
Foreign exchange instruments	—		—		(2)		—
Interest rate and foreign exchange instruments	—		—		(117)		—
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	182		91		(182)		(89)
Associated offsetting commodity contracts	(167)		(32)		167		32
Commodity contracts subject to rate recovery	27		25		(22)		(1)
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	44		111		(153)		(58)
Additional cash collateral for commodity contracts not subject to rate recovery	76		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	48		—		—		—
Total(1)	$	168	$	111	$	(153)	$	(58)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	26	$	25	$	(14)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	23		25		(11)		—
Additional cash collateral for commodity contracts subject to rate recovery	36		—		—		—
Total(1)	$	59	$	25	$	(11)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	1	$	—	$	(8)	$	(1)
Net amounts presented on the balance sheet	1		—		(8)		(1)
Additional cash collateral for commodity contracts subject to rate recovery	12		—		—		—
Total	$	13	$	—	$	(8)	$	(1)

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

DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
(Dollars in millions)
	December 31, 2021
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	6	$	(6)	$	(2)
Foreign exchange instruments	1		1		(1)		—
Interest rate and foreign exchange instruments	—		—		(1)		(130)
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	136		11		(122)		(10)
Associated offsetting commodity contracts	(93)		(8)		93		8
Commodity contracts subject to rate recovery	38		52		(58)		—
Associated offsetting commodity contracts	(8)		—		8		—
Net amounts presented on the balance sheet	74		62		(87)		(134)
Additional cash collateral for commodity contracts not subject to rate recovery	58		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	46		—		—		—
Total(1)	$	178	$	62	$	(87)	$	(134)
SDG&E:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	34	$	52	$	(20)	$	—
Associated offsetting commodity contracts	(5)		—		5		—
Net amounts presented on the balance sheet	29		52		(15)		—
Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(1)	$	57	$	52	$	(15)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	$	4	$	—	$	(38)	$	—
Associated offsetting commodity contracts	(3)		—		3		—
Net amounts presented on the balance sheet	1		—		(35)		—
Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total	$	19	$	—	$	(35)	$	—

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

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

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

CASH FLOW HEDGE IMPACTS
(Dollars in millions)
	Pretax gain (loss) recognized in OCI					Pretax gain (loss) reclassified from AOCI into earnings
	Three months ended June 30,					Three months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	13	$	(6)	Interest Expense	$	—	$	1
Interest rate instruments	50		(32)		Equity Earnings(1)	(13)		(19)
Foreign exchange instruments	—		(1)		Revenues: Energy- Related Businesses	1		—
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	—		(1)		Equity Earnings(1)	—		—
Interest rate and foreign exchange instruments	4		7		Interest Expense	1		—
					Other (Expense) Income, Net	—		7
Total	$	67	$	(33)		$	(12)	$	(11)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(1)	$	—
	Six months ended June 30,					Six months ended June 30,
	2022		2021		Location	2022		2021
Sempra:
Interest rate instruments	$	35	$	20	Interest Expense	$	1	$	(1)
Interest rate instruments	144		51		Equity Earnings(1)	(27)		(38)
Foreign exchange instruments	(3)		2		Revenues: Energy- Related Businesses	2		(1)
					Other (Expense) Income, Net	(1)		—
Foreign exchange instruments	(2)		2		Equity Earnings(1)	1		(1)
Interest rate and foreign exchange instruments	13		1		Interest Expense	1		—
					Other (Expense) Income, Net	6		1
Total	$	187	$	76		$	(17)	$	(40)
SoCalGas:
Interest rate instruments	$	—	$	—	Interest Expense	$	(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 (loss) gain on derivatives recognized in earnings
		Three months ended June 30,				Six months ended June 30,
	Location	2022		2021		2022		2021
Sempra:
Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(151)	$	(142)	$	(228)	$	(190)
Commodity contracts subject to rate recovery	Cost of Natural Gas	(4)		—		(4)		2
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	(24)		41		(6)		43
Foreign exchange instruments	Other (Expense) Income, Net	—		—		—		(24)
Total		$	(179)	$	(101)	$	(238)	$	(169)
SDG&E:
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	(24)	$	41	$	(6)	$	43
SoCalGas:
Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(4)	$	—	$	(4)	$	2

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures

RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Short-term investments held in Rabbi Trust	50		—		—		50
Interest rate instruments	—		32		—		32
Commodity contracts not subject to rate recovery	—		74		—		74
Effect of netting and allocation of collateral(2)	76		—		—		76
Commodity contracts subject to rate recovery	13		1		35		49
Effect of netting and allocation of collateral(2)	32		10		6		48
Support Agreement, net of related guarantee fees	—		—		16		16
Total	$	499	$	665	$	57	$	1,221
Liabilities:
Foreign exchange instruments	$	—	$	2	$	—	$	2
Interest rate and foreign exchange instruments	—		117		—		117
Commodity contracts not subject to rate recovery	—		72		—		72
Commodity contracts subject to rate recovery	—		18		2		20
Total	$	—	$	209	$	2	$	211

(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)
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Short-term investments held in Rabbi Trust	81		—		—		81
Interest rate instruments	—		6		—		6
Foreign exchange instruments	—		2		—		2
Commodity contracts not subject to rate recovery	—		46		—		46
Effect of netting and allocation of collateral(2)	58		—		—		58
Commodity contracts subject to rate recovery	12		1		69		82
Effect of netting and allocation of collateral(2)	31		9		6		46
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	601	$	649	$	82	$	1,332
Liabilities:
Interest rate instruments	$	—	$	8	$	—	$	8
Foreign exchange instruments	—		1		—		1
Interest rate and foreign exchange instruments	—		131		—		131
Commodity contracts not subject to rate recovery	—		31		—		31
Commodity contracts subject to rate recovery	—		35		15		50
Total	$	—	$	206	$	15	$	221

(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)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	15	$	—	$	—	$	15
Equity securities	283		5		—		288
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	30		13		—		43
Municipal bonds	—		293		—		293
Other securities	—		237		—		237
Total debt securities	30		543		—		573
Total nuclear decommissioning trusts(1)	328		548		—		876
Commodity contracts subject to rate recovery	13		—		35		48
Effect of netting and allocation of collateral(2)	30		—		6		36
Total	$	371	$	548	$	41	$	960
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	2	$	11
Total	$	—	$	9	$	2	$	11
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Commodity contracts subject to rate recovery	12		—		69		81
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	453	$	585	$	75	$	1,113
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	15	$	15
Total	$	—	$	—	$	15	$	15

(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)
	Fair value at June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	2		10		—		12
Total	$	2	$	11	$	—	$	13
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	9	$	—	$	9
Total	$	—	$	9	$	—	$	9
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	9		9		—		18
Total	$	9	$	10	$	—	$	19
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	35	$	—	$	35
Total	$	—	$	35	$	—	$	35

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

Recurring Fair Value Measures Level 3 Rollforward

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

LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Three months ended June 30,
	2022		2021
Balance at April 1	$	58	$	62
Realized and unrealized (losses) gains	(30)		8
Allocated transmission instruments	(6)		(2)
Settlements	11		12
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(23)	$	14
	Six months ended June 30,
	2022		2021
Balance at January 1	$	54	$	69
Realized and unrealized (losses) gains	(23)		6
Allocated transmission instruments	(6)		(2)
Settlements	8		7
Balance at June 30	$	33	$	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$	(18)	$	12

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

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

LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended June 30,
	2022		2021
Balance at April 1	$	12	$	3
Realized and unrealized gains(1)	6		3
Settlements	(2)		(2)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	5	$	2
	Six months ended June 30,
	2022		2021
Balance at January 1	$	7	$	3
Realized and unrealized gains(1)	14		5
Settlements	(5)		(4)
Balance at June 30(2)	$	16	$	4
Change in unrealized gains relating to instruments still held at June 30	$	13	$	4

(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 $9 in Other Long-term Assets at June 30, 2022 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
2022	$	(3.67)	to	$	6.96	$	(0.70)
2021	(1.81)		to	14.11		(0.12)

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

LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS
Settlement year	Price per MWh					Weighted-average price per MWh
2022	$	25.25	to	$	125.00	$	66.36
2021		22.45	to		151.90		49.27

Fair Value of Financial Instruments

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

FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
	Carrying amount		Fair value
			Level 1		Level 2		Level 3		Total
	June 30, 2022
Sempra:
Short-term amounts due from unconsolidated affiliates(1)	$	626	$	—	$	630	$	—	$	630
Long-term note receivable(2)	310		—		—		278		278
Long-term amounts due to unconsolidated affiliates	282		—		251		—		251
Total long-term debt(3)	23,924		—		21,709		—		21,709
SDG&E:
Total long-term debt(4)	$	7,800	$	—	$	7,102	$	—	$	7,102
SoCalGas:
Total long-term debt(5)	$	5,459	$	—	$	5,110	$	—	$	5,110
	December 31, 2021
Sempra:
Long-term note receivable(2)	$	300	$	—	$	—	$	327	$	327
Long-term amounts due from unconsolidated affiliates(1)	640		—		642		—		642
Long-term amounts due to unconsolidated affiliates	287		—		295		—		295
Total long-term debt(3)	20,099		—		22,126		—		22,126
SDG&E:
Total long-term debt(4)	$	6,417	$	—	$	7,236	$	—	$	7,236
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,367	$	—	$	5,367

(1)    Before allowances for credit losses of $1 at December 31, 2021. Includes $1 and $2 of accrued interest receivable at June 30, 2022 and December 31, 2021, respectively, in Due From Unconsolidated Affiliates – Current.

(2)    Before allowances for credit losses of $7 and $8 at June 30, 2022 and December 31, 2021, respectively. Excludes unamortized transaction costs of $5 at both June 30, 2022 and December 31, 2021, respectively.

(3)    Before reductions of unamortized discount and debt issuance costs of $294 and $260 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,334 and $1,335 at June 30, 2022 and December 31, 2021, respectively.

(4)    Before reductions of unamortized discount and debt issuance costs of $73 and $61 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $1,266 and $1,274 at June 30, 2022 and December 31, 2021, respectively.

(5)    Before reductions of unamortized discount and debt issuance costs of $43 and $36 at June 30, 2022 and December 31, 2021, respectively, and excluding finance lease obligations of $68 and $61 at June 30, 2022 and December 31, 2021, respectively.

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SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

6 Months Ended

Jun. 30, 2022

Public Utilities, General Disclosures [Abstract]

Schedule of Nuclear Decommissioning Trusts Investments

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 9.

NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
	June 30, 2022
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	43	$	1	$	(1)	$	43
Municipal bonds(2)	305		1		(13)		293
Other securities(3)	256		1		(20)		237
Total debt securities	604		3		(34)		573
Equity securities	109		187		(8)		288
Short-term investments, primarily cash equivalents	15		—		—		15
Receivables (payables), net	(13)		—		—		(13)
Total	$	715	$	190	$	(42)	$	863
	December 31, 2021
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	56	$	—	$	—	$	56
Municipal bonds	309		13		(1)		321
Other securities	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012

(1)    Maturity dates are 2023-2052.

(2)    Maturity dates are 2022-2056.

(3)    Maturity dates are 2022-2072.

Schedule of Sales of Securities By Nuclear Decommissioning Trusts

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

SALES OF SECURITIES IN THE NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Proceeds from sales	$	155	$	254	$	397	$	542
Gross realized gains	3		18		14		39
Gross realized losses	(7)		(1)		(11)		(3)

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COMMITMENTS AND CONTINGENCIES (Tables)

6 Months Ended

Jun. 30, 2022

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 June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sales-type leases:
Interest income	$	2	$	—	$	4	$	—
Total revenues from sales-type leases(1)	$	2	$	—	$	4	$	—
Operating leases:
Fixed lease payments	$	70	$	59	$	140	$	112
Variable lease payments	3		1		4		1
Total revenues from operating leases(1)	$	73	$	60	$	144	$	113
Depreciation expense	$	14	$	12	$	27	$	22

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

Sales-type Lease, Lease Income

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

LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Sales-type leases:
Interest income	$	2	$	—	$	4	$	—
Total revenues from sales-type leases(1)	$	2	$	—	$	4	$	—
Operating leases:
Fixed lease payments	$	70	$	59	$	140	$	112
Variable lease payments	3		1		4		1
Total revenues from operating leases(1)	$	73	$	60	$	144	$	113
Depreciation expense	$	14	$	12	$	27	$	22

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

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SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Segment Information

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

SEGMENT INFORMATION
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
REVENUES
SDG&E	$	1,399	$	1,318	$	2,844	$	2,655
SoCalGas	1,501		1,124		3,494		2,632
Sempra Infrastructure	689		341		1,113		790
All other	—		1		—		2
Adjustments and eliminations	(2)		(1)		—		(1)
Intersegment revenues(1)	(40)		(42)		(84)		(78)
Total	$	3,547	$	2,741	$	7,367	$	6,000
DEPRECIATION AND AMORTIZATION
SDG&E	$	244	$	220	$	483	$	433
SoCalGas	188		180		375		353
Sempra Infrastructure	67		59		132		113
All other	2		4		4		6
Total	$	501	$	463	$	994	$	905
INTEREST INCOME
SDG&E	$	1	$	—	$	1	$	1
SoCalGas	1		—		1		—
Sempra Infrastructure	9		20		30		41
All other	4		1		8		1
Intercompany eliminations	—		(6)		—		(9)
Total	$	15	$	15	$	40	$	34
INTEREST EXPENSE
SDG&E	$	114	$	101	$	220	$	203
SoCalGas	45		40		85		79
Sempra Infrastructure	32		45		59		86
All other	81		79		151		162
Intercompany eliminations	(1)		(7)		(1)		(13)
Total	$	271	$	258	$	514	$	517
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	42	$	33	$	106	$	78
SoCalGas	19		8		103		102
Sempra Infrastructure	70		94		161		151
All other	(51)		4		44		(34)
Total	$	80	$	139	$	414	$	297
EQUITY EARNINGS (LOSSES)
Equity earnings, before income tax:
Sempra Texas Utilities	$	3	$	2	$	5	$	3
Sempra Infrastructure	156		133		297		267
All other	—		50		—		50
	159		185		302		320
Equity earnings (losses), net of income tax:
Sempra Texas Utilities	184		137		346		273
Sempra Infrastructure	32		(9)		53		38
	216		128		399		311
Total	$	375	$	313	$	701	$	631

(1)    Revenues for reportable segments include intersegment revenues of $3, $23, and $14 for the three months ended June 30, 2022; $7, $49, and $28 for the six months ended June 30, 2022; $2, $23, and $17 for the three months ended June 30, 2021 and $4, $48, and $26 for the six months ended June 30, 2021 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.

SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	176	$	186	$	410	$	398
SoCalGas	87		94		421		501
Sempra Texas Utilities	186		138		348		273
Sempra Infrastructure	183		53		278		255
All other	(73)		(47)		(286)		(129)
Total	$	559	$	424	$	1,171	$	1,298
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E					$	1,090	$	1,072
SoCalGas					931		936
Sempra Infrastructure					336		415
All other					4		1
Total					$	2,361	$	2,424
					June 30, 2022		December 31, 2021
ASSETS
SDG&E					$	25,075	$	24,058
SoCalGas					21,354		20,324
Sempra Texas Utilities					13,406		13,047
Sempra Infrastructure					14,958		14,408
All other					1,984		1,399
Intersegment receivables					(1,195)		(1,191)
Total					$	75,582	$	72,045
EQUITY METHOD AND OTHER INVESTMENTS
Sempra Texas Utilities					$	13,406	$	13,047
Sempra Infrastructure					1,687		1,425
Total					$	15,093	$	14,472

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	6 Months Ended
	Jun. 30, 2022 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021		Jun. 30, 2021	Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 1,931	$ 559	[1]
Restricted cash, current	103	19	[1]
Restricted cash, noncurrent	59	3	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 2,093	$ 581		$ 371	$ 985

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	$ 1,670		$ 1,977
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	136	$ 138
Provisions for expected credit losses	77	66
Write-offs	(36)	(12)
Ending balance	177	192
Allowance for credit losses	7		8
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	142		94
Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	13		19
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	33		39
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	32		70
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	2		3
Other long-term assets | KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	7		8
Due from Unconsolidated Affiliates - Noncurrent
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses			1
Deferred Credits and Other | Sempra LNG
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit losses	6		7
San Diego Gas and Electric Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	716		751
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	66	69
Provisions for expected credit losses	37	13
Write-offs	(18)	(7)
Ending balance	85	75
San Diego Gas and Electric Company | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	62		42
San Diego Gas and Electric Company | Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	11		9
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	22		22
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	17		25
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	1		2
Southern California Gas Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	739		1,139
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	69	68
Provisions for expected credit losses	37	52
Write-offs	(18)	(5)
Ending balance	88	$ 115
Southern California Gas Company | Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	76		51
Southern California Gas Company | Accounts receivable – other, net
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	2		10
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable - trade and other, net	11		17
Southern California Gas Company | Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers	15		45
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Expected credit losses, noncurrent	$ 1		1
Customers Under California Arrearage Payment Program | San Diego Gas and Electric Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			63
Customers Under California Arrearage Payment Program | Southern California Gas Company
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivables from revenues from contracts with customers			$ 79

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Inventory [Line Items]
Natural gas	$ 138	$ 164
LNG	31	27
Materials and supplies	208	198
Total	377	389	[1]
San Diego Gas and Electric Company
Inventory [Line Items]
Natural gas	0	0
LNG	0	0
Materials and supplies	124	123
Total	124	123	[1]
Southern California Gas Company
Inventory [Line Items]
Natural gas	102	114
LNG	0	0
Materials and supplies	67	58
Total	$ 169	$ 172	[1]

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021	Oct. 31, 2021
Financing Receivable, Allowance for Credit Loss [Line Items]
Loan to KKR in exchange for interest-bearing promissory note			$ 300
Compound interest rate (as a percent)	5.00%
Other long-term assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Interest receivable	$ 308	$ 297
Other current assets
Financing Receivable, Allowance for Credit Loss [Line Items]
Interest receivable		$ 3

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 60	$ 55	$ 117	$ 114
San Diego Gas and Electric Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	26	28	54	58
Southern California Gas Company
Capitalized Financing Costs Disclosure [Line Items]
Capitalized interest costs	$ 17	$ 15	$ 35	$ 31

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Variable Interest Entities [Line Items]
Property plant and equipment, net	$ 45,402	$ 43,894	[1]
Finance lease obligations	1,334	1,335
Equity method investment	13,301	12,947	[1]
Investment in Oncor Holdings	13,301	12,947	[1]
Assets	75,582	72,045	[1]
Sempra Texas Utilities | Oncor Holdings
Variable Interest Entities [Line Items]
Equity method investment	13,301	12,947
Investment in Oncor Holdings	13,301	12,947
Sempra Infrastructure | Cameron LNG Holdings
Variable Interest Entities [Line Items]
Equity method investment	723	514
Investment in Oncor Holdings	723	514
Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entities [Line Items]
Maximum exposure under guarantor obligations	979
Sempra Infrastructure | Variable Interest Entity, Primary Beneficiary | ECA LNG JV
Variable Interest Entities [Line Items]
Assets	767	632
Liabilities	532	455
San Diego Gas and Electric Company
Variable Interest Entities [Line Items]
Property plant and equipment, net	20,741	20,048	[1]
Finance lease obligations	1,266	1,274
Assets	25,075	24,058	[1]
San Diego Gas and Electric Company | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entities [Line Items]
Property plant and equipment, net	1,206	1,217
Finance lease obligations	$ 1,206	$ 1,217
Oncor Electric Delivery Company LLC. | Oncor Holdings | Sempra Texas Utilities
Variable Interest Entities [Line Items]
Ownership interest (as a percent)	80.25%
Sempra Texas Holdings Corp | Oncor Holdings | Sempra Texas Intermediate Holding Company LLC
Variable Interest Entities [Line Items]
Ownership percentage in consolidated entity	100.00%

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Pension benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 42	$ 36	$ 83	$ 73
Interest cost	29	28	59	56
Expected return on assets	(45)	(43)	(91)	(86)
Amortization of:
Prior service cost (credit)	2	2	5	5
Actuarial loss (gain)	5	11	11	22
Settlement charges			0	7
Net periodic benefit cost (credit)	33	34	67	77
Regulatory adjustments	24	22	(3)	(7)
Total expense recognized	57	56	64	70
Pension benefits | San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	10	9	20	17
Interest cost	6	6	13	12
Expected return on assets	(11)	(13)	(22)	(25)
Amortization of:
Actuarial loss (gain)	1	1	1	1
Net periodic benefit cost (credit)	6	3	12	5
Regulatory adjustments	7	11	2	9
Total expense recognized	13	14	14	14
Pension benefits | Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	28	25	56	50
Interest cost	21	20	41	40
Expected return on assets	(33)	(30)	(64)	(58)
Amortization of:
Prior service cost (credit)	2	2	4	4
Actuarial loss (gain)	4	10	8	19
Net periodic benefit cost (credit)	22	27	45	55
Regulatory adjustments	17	11	(5)	(16)
Total expense recognized	39	38	40	39
Other postretirement benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	6	5	13	11
Interest cost	7	7	14	14
Expected return on assets	(16)	(15)	(32)	(30)
Amortization of:
Prior service cost (credit)	0	0	(1)	(1)
Actuarial loss (gain)	(3)	(2)	(7)	(4)
Settlement charges			0	0
Net periodic benefit cost (credit)	(6)	(5)	(13)	(10)
Regulatory adjustments	6	5	13	10
Total expense recognized	0	0	0	0
Other postretirement benefits | San Diego Gas and Electric Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1	3	2
Interest cost	2	2	3	3
Expected return on assets	(3)	(3)	(5)	(5)
Amortization of:
Actuarial loss (gain)	0	(1)	(1)	(1)
Net periodic benefit cost (credit)	0	(1)	0	(1)
Regulatory adjustments	0	1	0	1
Total expense recognized	0	0	0	0
Other postretirement benefits | Southern California Gas Company
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	4	10	8
Interest cost	6	6	11	11
Expected return on assets	(14)	(12)	(27)	(24)
Amortization of:
Prior service cost (credit)	0	0	(1)	(1)
Actuarial loss (gain)	(3)	(2)	(6)	(3)
Net periodic benefit cost (credit)	(6)	(4)	(13)	(9)
Regulatory adjustments	6	4	13	9
Total expense recognized	$ 0	$ 0	$ 0	$ 0

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Dedicated assets in support of certain benefit plans	$ 498	$ 567	[1]

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2022	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares		$ 559	$ 424	$ 1,171	$ 1,298
Earnings attributable to common shares		$ 559	$ 424	$ 1,171	$ 1,298
Weighted-average common shares outstanding for basic EPS (in shares)		314,845,000	307,800,000	315,595,000	304,372,000
Dilutive effect of stock options and RSUs (in shares)		1,022,000	807,000	1,052,000	846,000
Dilutive effect of mandatory convertible preferred stock (in shares)		0	0	0	1,066,000
Weighted-average common shares outstanding for diluted EPS (in shares)		315,867,000	308,607,000	316,647,000	306,284,000
Earnings per share, basic (dollars per share)		$ 1.78	$ 1.38	$ 3.71	$ 4.27
Earnings per share, diluted (in dollars per share)		$ 1.77	$ 1.37	$ 3.70	$ 4.24
Vested RSUs included in basic WASO (in shares)		399,000	447,000	403,000	454,000
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Non-qualified stock options granted (in shares)	219,898
Performance-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)	338,080
Service-based RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)	150,286
Stock options, RSAs and RSUs
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)		8,899	145,247	173,064	287,061
Convertible Preferred Stock
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)			4,256,725		4,256,725

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			$ 25,981
Ending balance		$ 26,841		26,841
Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(229)	$ (399)	(318)	$ (500)
OCI before reclassifications		39	(57)	122	18
Amounts reclassified from AOCI		23	12	29	38
Net OCI		62	(45)	151	56
Ending balance		(167)	(444)	(167)	(444)
Foreign currency translation adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(76)	(69)	(79)	(64)
OCI before reclassifications		1	(19)	4	(24)
Amounts reclassified from AOCI		10	0	10	0
Net OCI		11	(19)	14	(24)
Ending balance		(65)	(88)	(65)	(88)
AOCI associated with noncontrolling interests		9		9
Foreign currency translation adjustments | IEnova
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI associated with noncontrolling interests			24		24
Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(78)	(239)	(156)	(331)
OCI before reclassifications		37	(36)	111	37
Amounts reclassified from AOCI		11	10	15	29
Net OCI		48	(26)	126	66
Ending balance		(30)	(265)	(30)	(265)
Financial instruments | IEnova
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
AOCI associated with noncontrolling interests			14		14
Pension and other postretirement benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(75)	(91)	(83)	(105)
OCI before reclassifications		1	(2)	7	5
Amounts reclassified from AOCI		2	2	4	9
Net OCI		3	0	11	14
Ending balance		(72)	(91)	(72)	(91)
San Diego Gas and Electric Company
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			8,249
Ending balance		8,659		8,659
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		(10)	(10)	(10)	10
Ending balance		(10)	10	(10)	10
San Diego Gas and Electric Company | Pension and other postretirement benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(10)	(10)	(10)	10
Ending balance		(10)	10	(10)	10
Southern California Gas Company
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[2]			5,442
Ending balance		6,015		6,015
Southern California Gas Company | Total accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(30)	(31)	(31)	(31)
Amounts reclassified from AOCI		1	1	2	1
Net OCI		1	1	2	1
Ending balance		(29)	(30)	(29)	(30)
Southern California Gas Company | Financial instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(13)	(13)	(13)	(13)
Amounts reclassified from AOCI		1	0	1	0
Net OCI		1	0	1	0
Ending balance		(12)	(13)	(12)	(13)
Southern California Gas Company | Pension and other postretirement benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(17)	(18)	(18)	(18)
Amounts reclassified from AOCI		0	1	1	1
Net OCI		0	1	1	1
Ending balance		$ (17)	$ (17)	$ (17)	$ (17)

[1] Derived from audited financial statements.

[2] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Operation and Maintenance	$ 1,162	$ 1,024	$ 2,248	$ 2,025
Interest expense	(271)	(258)	(514)	(517)
Equity earnings	375	313	701	631
Energy-related businesses	654	307	1,037	721
Other Income, Net	(1)	72	37	107
Income before income taxes and equity earnings	364	281	1,029	1,049
Income tax expense	(80)	(139)	(414)	(297)
Net income	659	455	1,316	1,383
Earnings Attributable to Noncontrolling Interests	(88)	(10)	(122)	(43)
Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(45)	(40)	(85)	(79)
Other Income, Net	4	(2)	38	37
Income before income taxes and equity earnings	107	103	525	604
Income tax expense	(19)	(8)	(103)	(102)
Net income	88	95	422	502
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	14	12	20	38
Reclassification out of Accumulated Other Comprehensive Income | Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	1	2	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	1	0	1	0
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	12	11	17	40
Income tax expense	(4)	(1)	(5)	(9)
Net income	8	10	12	31
Earnings attributable to common shares	11	10	15	29
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]
Income before income taxes and equity earnings			1	1
Income tax expense			0	0
Net income			1	1
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest | Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	0	(1)	(1)	1
Equity earnings	13	19	27	38
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	0	1	0
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest | Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings			(1)	1
Energy-related businesses	(1)	0	(2)	1
Other Income, Net	1	0	1	0
Reclassification out of Accumulated Other Comprehensive Income | Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest | Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(1)	0	(1)	0
Other Income, Net	0	(7)	(6)	(1)
Reclassification out of Accumulated Other Comprehensive Income | Gains (Losses) on Cash Flow hedges Attributable to Noncontrolling Interests
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings Attributable to Noncontrolling Interests	3	0	3	(2)
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	2	1	4	3
Reclassification out of Accumulated Other Comprehensive Income | Amortization of actuarial loss | Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net			1	0
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net	1	1	2	2
Reclassification out of Accumulated Other Comprehensive Income | Amortization of prior service cost | Southern California Gas Company
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income (Expense), Net	0	1	0	1
Reclassification out of Accumulated Other Comprehensive Income | Settlement charges
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Income, Net			0	7
Reclassification out of Accumulated Other Comprehensive Income | Pension and other postretirement benefits
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings	3	2	6	12
Income tax expense	(1)	0	(2)	(3)
Net income	$ 2	$ 2	$ 4	$ 9

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) $ / shares in Units, $ in Millions				1 Months Ended	3 Months Ended	6 Months Ended
	Jun. 01, 2022 USD ($)	Apr. 06, 2022 USD ($) $ / shares shares	Jan. 11, 2022 USD ($) $ / shares shares	May 31, 2021 USD ($) shares	Jun. 30, 2022 USD ($) shares	Jun. 30, 2022 USD ($) shares	Jun. 30, 2021 USD ($)	Aug. 01, 2022 shares	Dec. 21, 2021 USD ($)	Oct. 15, 2021 $ / shares	Apr. 30, 2021	Jan. 15, 2021 shares
Subsidiary, Sale of Stock [Line Items]
Sale					$ 1,418	$ 1,418	$ 5
Shares issued (in shares) | shares				12,306,777
Series A Preferred Stock
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares												17,250,000
Preferred stock, conversion ratio												0.7989
Common stock
Subsidiary, Sale of Stock [Line Items]
Shares converted | shares												13,781,025
Accelerated share repurchase program, prepaid amount		$ 250	$ 200
Share repurchase program, number of shares repurchased (in shares) | shares		1,471,957	1,472,756
Common stock repurchased, average price (in dollars per share) | $ / shares		$ 169.84	$ 135.80
Infraestructura Energética Nova
Subsidiary, Sale of Stock [Line Items]
Common stock acquired (in shares) | shares				381,015,194
Common stock exchange ratio				0.0323
SI Partners | Sempra Infrastructure
Subsidiary, Sale of Stock [Line Items]
Sale	$ 709
Sale of noncontrolling interest, change in equity	709
Sale of noncontrolling interest, transaction costs	12
Sale of noncontrolling interest, deferred income tax liability	301
Sale of noncontrolling interest, transaction costs reimbursed	$ 10
SI Partners | Abu Dhabi Investment Authority
Subsidiary, Sale of Stock [Line Items]
Sale of noncontrolling interest (as a percent)									10.00%
Sale of noncontrolling interest, aggregate purchase price									$ 1,700
SI Partners | Sempra Energy
Subsidiary, Sale of Stock [Line Items]
Ownership percentage									70.00%
SI Partners | KKR
Subsidiary, Sale of Stock [Line Items]
Ownership percentage									20.00%
SI Partners | Abu Dhabi Investment Authority
Subsidiary, Sale of Stock [Line Items]
Ownership percentage									10.00%
IEnova
Subsidiary, Sale of Stock [Line Items]
Ownership interest (as a percent)	99.90%			96.40%							70.20%
Decrease in equity				$ 1,400
Increase in stockholders' equity				1,400
Transaction costs				$ 12
Amount held in trust for purchasing shares (in shares) | shares					1,212,981	1,212,981
Share price (in pesos per share) | $ / shares										$ 78.97
IEnova | Subsequent Event
Subsidiary, Sale of Stock [Line Items]
Amount held in trust for purchasing shares (in shares) | shares								851,211
Infraestructura Energética Nova | KKR
Subsidiary, Sale of Stock [Line Items]
Noncontrolling interest, percent of funding	20.00%
Infraestructura Energética Nova | Abu Dhabi Investment Authority
Subsidiary, Sale of Stock [Line Items]
Noncontrolling interest, percent of funding	10.00%

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 2,192	$ 1,418	[1]
SI Partners | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage	30.00%	20.00%
Other noncontrolling interests	$ 2,146	$ 1,384
IEnova subsidiaries | Sempra Infrastructure
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 46	$ 34
IEnova subsidiaries | Sempra Infrastructure | Minimum
Noncontrolling Interest [Line Items]
Ownership percentage	0.10%	0.10%
IEnova subsidiaries | Sempra Infrastructure | Maximum
Noncontrolling Interest [Line Items]
Ownership percentage	16.60%	16.60%

[1] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details)		6 Months Ended	12 Months Ended
	Mar. 15, 2022 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)		Dec. 31, 2021 MXN ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		$ 646,000,000	$ 23,000,000	[1]
Due from unconsolidated affiliates - noncurrent		0	637,000,000	[1]
Due to unconsolidated affiliates - noncurrent		(282,000,000)	(287,000,000)	[1]
Maximum borrowing capacity		9,535,000,000
Various affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		20,000,000	21,000,000
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current		(68,000,000)	(97,000,000)	[1]
Maximum borrowing capacity		1,500,000,000
San Diego Gas and Electric Company | Various affiliates
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current		(12,000,000)	(9,000,000)
San Diego Gas and Electric Company | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current		(26,000,000)	(40,000,000)
Income taxes due (to) from Sempra Energy		21,000,000	19,000,000
San Diego Gas and Electric Company | Due to/from SoCalGas
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current		(30,000,000)	(48,000,000)
Southern California Gas Company
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		31,000,000	49,000,000	[1]
Due to unconsolidated affiliates, current		(36,000,000)	(36,000,000)	[2]
Maximum borrowing capacity		750,000,000
Southern California Gas Company | Various affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		1,000,000	1,000,000
Southern California Gas Company | Due to/from Sempra Energy
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current		(36,000,000)	(36,000,000)
Income taxes due (to) from Sempra Energy		6,000,000	6,000,000
Southern California Gas Company | Due to/from SDG&E
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		30,000,000	48,000,000
Sempra Infrastructure
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent		(282,000,000)	(287,000,000)
Debt amount	$ 625,000,000
Sempra Infrastructure | IMG
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current		626,000,000	2,000,000
Due from unconsolidated affiliates - noncurrent		0	637,000,000
Due from affiliates, allowance for credit loss			1,000,000
Maximum borrowing capacity			691,000,000		$ 14,200,000,000
Accrued interest receivable		$ 1,000,000	$ 2,000,000
Sempra Infrastructure | IMG | Interbank Equilibrium Rate
Related Party Transaction [Line Items]
Spread on variable rate (as a percent)			2.20%
Sempra Infrastructure | IMG | Secured Overnight Financing Rate
Related Party Transaction [Line Items]
Spread on variable rate (as a percent)	1.80%
Interest rate on due from affiliate, current		3.41%
Five Point Five Percent Note Due January 2024 | Sempra Infrastructure | TAG Pipeline Norte
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)		5.50%
Due to unconsolidated affiliates - noncurrent		$ (39,000,000)	$ (69,000,000)
Five Point Five Percent Note Due January 2025 | Sempra Infrastructure | TAG Pipeline Norte
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)		5.50%
Due to unconsolidated affiliates - noncurrent		$ (22,000,000)	(21,000,000)
Five Point Five Percent Notes Due July 2025 | Sempra Infrastructure | TAG Pipeline Norte
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)		5.50%
Due to unconsolidated affiliates - noncurrent		$ (21,000,000)	(20,000,000)
Five Point Five Percent Note due January 2026 | Sempra Infrastructure | TAG Pipeline Norte
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)		5.50%
Due to unconsolidated affiliates - noncurrent		$ (18,000,000)	0
Five Point Seven Four Percent Note December 2029 | Sempra Infrastructure | TAG
Related Party Transaction [Line Items]
Stated rate of debt (as a percent)		5.74%
Due to unconsolidated affiliates - noncurrent		$ (182,000,000)	$ (177,000,000)

[1] Derived from audited financial statements.

[2] Derived from audited financial statements.

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GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Related Party Transaction [Line Items]
Revenue from related parties	$ 15	$ 7	$ 22	$ 15
Costs of sales to related parties	0	0	0	11
Interest income	4	12	14	27
Interest expense	4	3	8	7
San Diego Gas and Electric Company
Related Party Transaction [Line Items]
Revenue from related parties	4	2	8	4
Costs of sales to related parties	26	27	50	55
Southern California Gas Company
Related Party Transaction [Line Items]
Revenue from related parties	23	23	49	48
Costs of sales to related parties	$ (4)	$ 0	$ (4)	$ 3

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER (EXPENSE) INCOME, NET (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Other Income [Line Items]
Allowance for equity funds used during construction	$ 34	$ 34	$ 69	$ 72
Investment (losses) gains, net	(34)	19	(47)	28
(Losses) gains on interest rate and foreign exchange instruments, net	(1)	7	5	(23)
Foreign currency transaction (losses) gains, net	(3)	26	(22)	7
Non-service components of net periodic benefit (cost) credit	(9)	(15)	32	14
Interest on regulatory balancing accounts, net	4	2	5	3
Sundry, net	8	(1)	(5)	6
Total	(1)	72	37	107
San Diego Gas and Electric Company
Other Income [Line Items]
Allowance for equity funds used during construction	21	22	42	45
Non-service components of net periodic benefit (cost) credit	(2)	(4)	9	5
Interest on regulatory balancing accounts, net	3	2	4	3
Sundry, net	0	2	1	4
Total	22	22	56	57
Southern California Gas Company
Other Income [Line Items]
Allowance for equity funds used during construction	13	11	26	23
Non-service components of net periodic benefit (cost) credit	(6)	(9)	26	19
Interest on regulatory balancing accounts, net	1	0	1	0
Sundry, net	(4)	(4)	(15)	(5)
Total	$ 4	(2)	38	37
IMG
Other Income [Line Items]
Foreign currency transaction (losses) gains, net		$ 28	$ (11)	$ 5

XML

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 80	$ 139	$ 414	$ 297
Income before income taxes and equity earnings	364	281	1,029	1,049
Equity earnings, before income tax:	159	185	302	320
Pretax income	$ 523	$ 466	$ 1,331	$ 1,369
Effective income tax rate (as a percent)	15.00%	30.00%	31.00%	22.00%
Deferred income tax liability for foreign earnings	$ 120		$ 120
San Diego Gas and Electric Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	42	$ 33	106	$ 78
Income before income taxes and equity earnings	$ 218	$ 219	$ 516	$ 476
Effective income tax rate (as a percent)	19.00%	15.00%	21.00%	16.00%
Southern California Gas Company
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 19	$ 8	$ 103	$ 102
Income before income taxes and equity earnings	107	103	525	604
Pretax income	$ 107	$ 103	$ 525	$ 604
Effective income tax rate (as a percent)	18.00%	8.00%	20.00%	17.00%

XML

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,033	$ 2,470	$ 6,722	$ 5,611
Utilities regulatory revenues	303	210	328	182
Other revenues	211	61	317	207
Total revenues	3,547	2,741	7,367	6,000
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,590	2,224	6,002	5,097
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	443	246	720	514
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,827	1,385	4,272	3,503
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,206	1,085	2,450	2,108
Operating Segments | San Diego Gas and Electric Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,250	1,170	2,751	2,386
Utilities regulatory revenues	149	148	93	269
Other revenues	0	0	0	0
Total revenues	1,399	1,318	2,844	2,655
Operating Segments | San Diego Gas and Electric Company | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,250	1,170	2,751	2,386
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	159	162	489	435
Operating Segments | San Diego Gas and Electric Company | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,091	1,008	2,262	1,951
Operating Segments | Southern California Gas Company
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,347	1,062	3,259	2,719
Utilities regulatory revenues	154	62	235	(87)
Other revenues	0	0	0	0
Total revenues	1,501	1,124	3,494	2,632
Operating Segments | Southern California Gas Company | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,347	1,062	3,259	2,719
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	1,347	1,062	3,259	2,719
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	477	277	797	573
Utilities regulatory revenues	0	0	0	0
Other revenues	212	64	316	217
Total revenues	689	341	1,113	790
Operating Segments | Sempra Infrastructure | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	20	17	48	44
Operating Segments | Sempra Infrastructure | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	457	260	749	529
Operating Segments | Sempra Infrastructure | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	340	185	569	397
Operating Segments | Sempra Infrastructure | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	137	92	228	176
Consolidation, Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(41)	(39)	(85)	(67)
Utilities regulatory revenues	0	0	0	0
Other revenues	(1)	(3)	1	(10)
Total revenues	(42)	(42)	(84)	(77)
Consolidation, Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(27)	(25)	(56)	(52)
Consolidation, Eliminations | Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(14)	(14)	(29)	(15)
Consolidation, Eliminations | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(19)	(24)	(45)	(48)
Consolidation, Eliminations | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (22)	$ (15)	$ (40)	$ (19)

XML

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Jun. 30, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 6,260
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 200
Revenues to be recognized, period of recognition	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 384
Revenues to be recognized, period of recognition	1 year
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	$ 385
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	$ 384
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	$ 382
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	$ 4,525
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	$ 81
San Diego Gas and Electric Company | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 2
Revenues to be recognized, period of recognition	6 months
San Diego Gas and Electric Company | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
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]: 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	$ 63
Revenues to be recognized, period of recognition

XML

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (278)	$ (207)
Revenue from performance obligations satisfied during reporting period	86	49
Payments received in advance	(105)	(1)
Contract liabilities, closing balance	(297)	(159)
Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(81)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(216)
San Diego Gas and Electric Company
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	(83)	(87)
Revenue from performance obligations satisfied during reporting period	2	2
Contract liabilities, closing balance	(81)	$ (85)
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	$ (77)

XML

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,670	$ 1,977
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,620	1,886
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	13	19
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	5	2
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	32	70
San Diego Gas and Electric Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	716	751
San Diego Gas and Electric Company | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	685	715
San Diego Gas and Electric Company | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	11	9
San Diego Gas and Electric Company | Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	3	2
San Diego Gas and Electric Company | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	17	25
Southern California Gas Company
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	739	1,139
Southern California Gas Company | Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	722	1,084
Southern California Gas Company | Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	10
Southern California Gas Company | Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 15	$ 45

XML

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (992)	$ (1,479)
San Diego Gas and Electric Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	453	358
San Diego Gas and Electric Company | Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(24)	(50)
San Diego Gas and Electric Company | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	176	125
San Diego Gas and Electric Company | Pension and other postretirement benefit plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(8)	(7)
San Diego Gas and Electric Company | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,185)	(2,251)
San Diego Gas and Electric Company | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	61	62
San Diego Gas and Electric Company | Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	121	122
San Diego Gas and Electric Company | Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	246	77
San Diego Gas and Electric Company | Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	33	49
San Diego Gas and Electric Company | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	80	67
San Diego Gas and Electric Company | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(117)	(107)
San Diego Gas and Electric Company | Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	255	178
San Diego Gas and Electric Company | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	102	110
San Diego Gas and Electric Company | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(17)	207
San Diego Gas and Electric Company | Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	132	119
San Diego Gas and Electric Company | Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,145)	(1,299)
Southern California Gas Company
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	601	410
Southern California Gas Company | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	113	44
Southern California Gas Company | Pension and other postretirement benefit plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	39	51
Southern California Gas Company | Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(603)	(627)
Southern California Gas Company | Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	31	31
Southern California Gas Company | Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	34	34
Southern California Gas Company | Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(46)	(146)
Southern California Gas Company | Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	425	339
Southern California Gas Company | Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(213)	(183)
Southern California Gas Company | Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	18	16
Southern California Gas Company | Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	125	42
Southern California Gas Company | Other regulatory assets, net
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	153	142
Southern California Gas Company | Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	76	(257)
Sempra Infrastructure | Deferred income taxes recoverable in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 77	$ 77

XML

REGULATORY MATTERS - GENERAL RATE CASE (Details) - 2024 GRC - 2024 Requirement - General Rate Case $ in Billions	1 Months Ended
	May 31, 2022 USD ($)
San Diego Gas and Electric Company
General Rate Case [Line Items]
Requested revenue requirements	$ 3.0
San Diego Gas and Electric Company | Minimum
General Rate Case [Line Items]
Estimate of annual increases	8.00%
San Diego Gas and Electric Company | Maximum
General Rate Case [Line Items]
Estimate of annual increases	12.00%
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%

XML

REGULATORY MATTERS - COST OF CAPITAL & FERC (Details) - California Public Utilities Commission - USD ($)	1 Months Ended		12 Months Ended		36 Months Ended
	Apr. 30, 2022	Feb. 28, 2022	Sep. 30, 2021	Dec. 31, 2019	Dec. 31, 2022	Jan. 01, 2022
Public Utilities, General Disclosures [Line Items]
Variable rate (as a percent)				1.00%
San Diego Gas and Electric Company
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)				4.498%
Authorized weighting (as a percent)	100.00%
Weighted return on rate base (as a percent)	7.48%
Percentage below CCM benchmark rate			1.17%
Authorized ROE (as a percent)				10.20%		9.62%
San Diego Gas and Electric Company | Forecast
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)					100.00%
Weighted return on rate base (as a percent)					7.55%
San Diego Gas and Electric Company | Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	46.00%
San Diego Gas and Electric Company | Authorized Weighting | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	54.00%
San Diego Gas and Electric Company | Authorized Weighting | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.00%
San Diego Gas and Electric Company | Authorized Weighting | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					45.25%
San Diego Gas and Electric Company | Authorized Weighting | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					52.00%
San Diego Gas and Electric Company | Authorized Weighting | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					2.75%
San Diego Gas and Electric Company | Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	3.87%
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)	10.55%
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)	0.00%
San Diego Gas and Electric Company | Return on Rate Base | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					4.59%
San Diego Gas and Electric Company | Return on Rate Base | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					10.20%
San Diego Gas and Electric Company | Return on Rate Base | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					6.22%
San Diego Gas and Electric Company | Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	1.78%
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)	5.70%
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)	0.00%
San Diego Gas and Electric Company | Weighted Return on Rate Base | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					2.08%
San Diego Gas and Electric Company | Weighted Return on Rate Base | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					5.30%
San Diego Gas and Electric Company | Weighted Return on Rate Base | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					0.17%
Southern California Gas Company
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)				4.029%
Authorized weighting (as a percent)	100.00%
Weighted return on rate base (as a percent)	7.60%
Southern California Gas Company | Forecast
Public Utilities, General Disclosures [Line Items]
Authorized weighting (as a percent)					100.00%
Weighted return on rate base (as a percent)					7.30%
Southern California Gas Company | Energy Efficiency Program Inquiry
Public Utilities, General Disclosures [Line Items]
Equity losses on investment		$ 10,000,000
Southern California Gas Company | Energy Efficiency and Advocacy
Public Utilities, General Disclosures [Line Items]
Equity losses on investment		$ 150,000
Southern California Gas Company | Authorized Weighting
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	45.60%
Southern California Gas Company | Authorized Weighting | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	54.00%
Southern California Gas Company | Authorized Weighting | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.40%
Southern California Gas Company | Authorized Weighting | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					45.60%
Southern California Gas Company | Authorized Weighting | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					52.00%
Southern California Gas Company | Authorized Weighting | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					2.40%
Southern California Gas Company | Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	3.89%
Southern California Gas Company | Return on Rate Base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	10.75%
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%
Southern California Gas Company | Return on Rate Base | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					4.23%
Southern California Gas Company | Return on Rate Base | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					10.05%
Southern California Gas Company | Return on Rate Base | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					6.00%
Southern California Gas Company | Weighted Return on Rate Base
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)	1.77%
Southern California Gas Company | Weighted Return on Rate Base | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	5.81%
Southern California Gas Company | Weighted Return on Rate Base | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)	0.02%
Southern California Gas Company | Weighted Return on Rate Base | Forecast
Public Utilities, General Disclosures [Line Items]
Approved debt capital structure (as a percent)					1.93%
Southern California Gas Company | Weighted Return on Rate Base | Forecast | Common Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					5.23%
Southern California Gas Company | Weighted Return on Rate Base | Forecast | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Approved return on equity (as a percent)					0.14%

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ACQUISITIONS AND DIVESTITURES - ACQUISITION ACTIVITY (Details) - Saavi Energia $ in Millions	1 Months Ended
	Mar. 31, 2021 USD ($) MW	Mar. 01, 2021	Feb. 28, 2021
Saavi Energia Asset Acquisition | Sempra Infrastructure
Business Acquisition [Line Items]
Purchase price	$ 65
Cash acquired	14
Debt assumed	277
Related party note payable assumed	94
Subsequent acquisition, percentage		100.00%
Equity interest in acquiree, fair value	34
Assets acquired	458
Liabilities assumed	$ 345
Power generation facility, nameplate capacity (in MW) | MW	155
Intangible assets acquired	$ 190
Intangible assets acquired, useful life	14 years
Second power generation facility, nameplate capacity (in MW) | MW	108
ESJ
Business Acquisition [Line Items]
Ownership percentage	50.00%
ESJ | Sempra Infrastructure
Business Acquisition [Line Items]
Ownership percentage			50.00%

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INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	1 Months Ended		6 Months Ended
	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($) projectOwner	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 29, 2021 bank	Mar. 31, 2021	Feb. 28, 2021
Schedule of Equity Method Investments [Line Items]
Distributions from investments			$ 403	$ 532
Distributions from investments			0	4
Sempra Texas Utilities | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Contribution	$ 100		171	100
Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			16
Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Distributions from investments			233	378
Investments made during period			$ 10
Corporate Joint Venture | Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Number of project owners | projectOwner		4
Proceeds from related party debt		$ 1,500
Number of project owners sending direct proceeds | projectOwner		2
Number of project owners sending proceeds from external lenders | projectOwner		2
Liability cap (as a percent)			130.00%
Liability cap, amount			$ 979
Corporate Joint Venture | Sempra Infrastructure | Cameron LNG JV | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related party debt		$ 753
Distributions from investments		$ 753
Number of banks | bank					8
Oncor Holdings | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Distributions from investments			$ 170	162
ESJ | IEnova | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest						50.00%
Oncor Holdings | Sempra Texas Holdings Corp | Sempra Texas Intermediate Holding Company LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity			100.00%
Oncor Electric Delivery Company LLC. | Oncor Holdings | Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest			80.25%
Cameron LNG JV | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity			50.20%
ESJ | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Distributions from investments				4
ESJ | ESJ | IEnova | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage							50.00%
TAG | Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Distributions from investments			$ 32
Other current assets | Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			7
Other long-term assets | Sempra Infrastructure | Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			9
Promissory Note for SDSRA Distribution | Corporate Joint Venture | Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Distributions from investments	165
Promissory Note for SDSRA Distribution | Other Current Liabilities | Corporate Joint Venture | Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Guarantees, carrying value			$ 21
Promissory Note for SDSRA Distribution | Deferred Credits and Other | Corporate Joint Venture | Sempra Infrastructure | Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Senior note, liability	$ 22			$ 22

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INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Schedule of Equity Method Investments [Line Items]
Net income (loss)	$ 659	$ 455	$ 1,316	$ 1,383
Equity Method Investment, Nonconsolidated Investee or Group of Investees | Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Operating revenues	1,293	1,147	2,542	2,286
Operating expenses	(908)	(836)	(1,805)	(1,665)
Operating income	385	311	737	621
Interest expense	(108)	(102)	(216)	(204)
Income tax expense	(52)	(34)	(94)	(70)
Net income (loss)	226	167	417	332
Noncontrolling interest held by Texas Transmission Investment LLC	(46)	(34)	(84)	(67)
Earnings attributable to Sempra Energy	$ 180	$ 133	$ 333	$ 265

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DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details)	6 Months Ended
	Jun. 30, 2022 USD ($) customer	Mar. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)
Line of Credit [Line Items]
Maximum borrowing capacity	$ 9,535,000,000
Primary committed lines of credit | customer	7
Amount outstanding	$ (595,000,000)
Available unused credit	$ 8,898,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)	65.00%
Uncommitted letters of credit outstanding	$ 730,000,000
Commercial Paper
Line of Credit [Line Items]
Commercial paper outstanding	(42,000,000)
Letter of Credit
Line of Credit [Line Items]
Uncommitted letters of credit outstanding	730,000,000
Sempra Energy
Line of Credit [Line Items]
Maximum borrowing capacity	3,185,000,000
Amount outstanding	0
Available unused credit	3,143,000,000
Sempra Energy | Sempra Energy Line Of Credit Due May 2024
Line of Credit [Line Items]
Maximum borrowing capacity	1,250,000,000
Amount outstanding	0
Available unused credit	1,250,000,000
Sempra Energy | Commercial Paper
Line of Credit [Line Items]
Commercial paper outstanding	(42,000,000)
Sempra Energy | Commercial Paper | Sempra Energy Line Of Credit Due May 2024
Line of Credit [Line Items]
Commercial paper outstanding	0
San Diego Gas and Electric Company
Line of Credit [Line Items]
Maximum borrowing capacity	1,500,000,000
Amount outstanding	0
Available unused credit	$ 1,500,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)	65.00%
San Diego Gas and Electric Company | Commercial Paper
Line of Credit [Line Items]
Commercial paper outstanding	$ 0
San Diego Gas and Electric Company | Letter of Credit
Line of Credit [Line Items]
Uncommitted letters of credit outstanding	15,000,000
Southern California Gas Company
Line of Credit [Line Items]
Maximum borrowing capacity	750,000,000
Amount outstanding	0
Available unused credit	$ 750,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)	65.00%
Southern California Gas Company | Commercial Paper
Line of Credit [Line Items]
Commercial paper outstanding	$ 0
Southern California Gas Company | Letter of Credit
Line of Credit [Line Items]
Uncommitted letters of credit outstanding	20,000,000
SI Partners
Line of Credit [Line Items]
Maximum borrowing capacity	1,000,000,000
Amount outstanding	(285,000,000)
Available unused credit	$ 715,000,000
Debt covenant, ratio of adjusted net indebtedness to earnings	5.25
SI Partners | Commercial Paper
Line of Credit [Line Items]
Commercial paper outstanding	$ 0
IEnova | IEnova Committed Line Of Credit Due 2023
Line of Credit [Line Items]
Maximum borrowing capacity	350,000,000
Amount outstanding	(310,000,000)
Available unused credit	40,000,000
IEnova | IEnova Committed Line Of Credit Due 2024
Line of Credit [Line Items]
Maximum borrowing capacity	1,500,000,000
Amount outstanding	0
Available unused credit	1,500,000,000
IEnova | Commercial Paper | IEnova Committed Line Of Credit Due 2023
Line of Credit [Line Items]
Commercial paper outstanding	0
IEnova | Commercial Paper | IEnova Committed Line Of Credit Due 2024
Line of Credit [Line Items]
Commercial paper outstanding	0
Sempra Infrastructure | Foreign Unsecured Line of Credit
Line of Credit [Line Items]
Maximum borrowing capacity	570,000,000
Amount outstanding	(318,000,000)
Available unused credit	252,000,000
Sempra Infrastructure | Foreign Line of Credit | Foreign Uncommitted Revolving Credit Facility September 2022
Line of Credit [Line Items]
Maximum borrowing capacity	250,000,000
Amount outstanding	(250,000,000)
Available unused credit	0
Sempra Infrastructure | Foreign Line of Credit | Foreign Uncommitted Revolving Credit Facility Due October 2023
Line of Credit [Line Items]
Maximum borrowing capacity	100,000,000
Amount outstanding	(36,000,000)
Available unused credit	64,000,000
Sempra Infrastructure | Foreign Line of Credit | Foreign Uncommitted Revolving Credit Facility Due October 2023-2
Line of Credit [Line Items]
Maximum borrowing capacity	20,000,000
Amount outstanding	0
Available unused credit	20,000,000
Sempra Infrastructure | Letter of Credit
Line of Credit [Line Items]
Uncommitted letters of credit outstanding	525,000,000
Sempra LNG | Foreign Line of Credit | Foreign Uncommitted Revolving Credit Facility Due August 2023
Line of Credit [Line Items]
Maximum borrowing capacity	200,000,000	$ 200,000,000	$ 100,000,000
Amount outstanding	(32,000,000)
Available unused credit	168,000,000
Parent and Other | Letter of Credit
Line of Credit [Line Items]
Uncommitted letters of credit outstanding	$ 170,000,000

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DEBT AND CREDIT FACILITIES - TERM LOAN (Details) - Term Loan Due 2023 - Southern California Gas Company - USD ($)	1 Months Ended	3 Months Ended
	Jul. 31, 2022	Oct. 07, 2022
Forecast
Short-Term Debt [Line Items]
Maximum borrowing request		$ 800,000,000
Secured Debt | Subsequent Event
Short-Term Debt [Line Items]
Debt amount	$ 800,000,000
Term of debt instrument	364 days
Debt Instrument, Basis Spread on Variable Rate	0.70%

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DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details)	Jun. 30, 2022	Dec. 31, 2021
Sempra
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	2.70%	0.60%
San Diego Gas and Electric Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.00%	0.65%
Southern California Gas Company
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	0.00%	0.21%

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DEBT AND CREDIT FACILITIES - LONG-TERM DEBT (Details)	1 Months Ended				3 Months Ended
	Mar. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)	Jan. 31, 2022 USD ($)	Dec. 31, 2020 USD ($) bank	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Jul. 31, 2022 USD ($) bank	Dec. 31, 2021 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 9,535,000,000
Sempra Energy
Debt Instrument [Line Items]
Maximum borrowing capacity					3,185,000,000
Sempra Energy | Three Point Three Percent Senior Unsecured Notes
Debt Instrument [Line Items]
Debt amount	$ 750,000,000					$ 750,000,000
Stated rate of debt (as a percent)	3.30%					3.30%
Proceeds from debt issuance	$ 745,000,000
Unamortized debt issuance costs	5,000,000					$ 5,000,000
Sempra Energy | Three Point Seven Zero Percent Senior Unsecured Notes
Debt Instrument [Line Items]
Debt amount	$ 500,000,000					$ 500,000,000
Stated rate of debt (as a percent)	3.70%					3.70%
Proceeds from debt issuance	$ 494,000,000
Unamortized debt issuance costs	6,000,000					$ 6,000,000
San Diego Gas and Electric Company
Debt Instrument [Line Items]
Maximum borrowing capacity					1,500,000,000
San Diego Gas and Electric Company | Term Loan Due 2024
Debt Instrument [Line Items]
Debt amount		$ 400,000,000
Proceeds from debt issuance					200,000,000	200,000,000
Term of debt instrument		2 years
Spread on variable rate (as a percent)		0.625%
San Diego Gas and Electric Company | Three Point Zero Percent First Mortgage Bonds
Debt Instrument [Line Items]
Debt amount	$ 500,000,000					$ 500,000,000
Stated rate of debt (as a percent)	3.00%					3.00%
Proceeds from debt issuance	$ 494,000,000
Unamortized debt issuance costs	6,000,000					$ 6,000,000
San Diego Gas and Electric Company | Three Point Seven Zero Percent First Mortgage Bonds
Debt Instrument [Line Items]
Debt amount	$ 500,000,000					$ 500,000,000
Stated rate of debt (as a percent)	3.70%					3.70%
Proceeds from debt issuance	$ 492,000,000
Unamortized debt issuance costs	8,000,000					$ 8,000,000
Southern California Gas Company
Debt Instrument [Line Items]
Maximum borrowing capacity					750,000,000
Southern California Gas Company | Two Point Nine Five Percent Senior Unsecured Notes
Debt Instrument [Line Items]
Debt amount	$ 700,000,000					$ 700,000,000
Stated rate of debt (as a percent)	2.95%					2.95%
Proceeds from debt issuance	$ 691,000,000
Unamortized debt issuance costs	$ 9,000,000					$ 9,000,000
SI Partners
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 1,000,000,000
SI Partners | Senior Notes 3.25% Due 2032
Debt Instrument [Line Items]
Debt amount			$ 400,000,000
Stated rate of debt (as a percent)			3.25%
Proceeds from debt issuance			$ 390,000,000
Unamortized debt issuance costs			$ 10,000,000
Sempra LNG | Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Debt Instrument [Line Items]
Term of debt instrument				5 years
Number of banks in syndicate | bank				9
Weighted average interest rate (as a percent)					4.37%			2.93%
Sempra LNG | Loan Agreement To Finance Natural Gas Liquefaction Export Facility | Subsequent Event
Debt Instrument [Line Items]
Number of banks in syndicate | bank							9
Sempra LNG | Loan Agreement To Finance Natural Gas Liquefaction Export Facility, Number Of Banks Replaced In Amendment
Debt Instrument [Line Items]
Debt outstanding					$ 61,000,000
Sempra LNG | Loan Agreement To Finance Natural Gas Liquefaction Export Facility, Number Of Banks Replaced In Amendment | Subsequent Event
Debt Instrument [Line Items]
Maximum borrowing capacity							$ 203,000,000
Number of banks in lending group replaced							2
Number of banks in syndicate after amendment | bank							7
Subsidiary of TOTAL SE | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity				16.60%
Sempra Infrastructure | ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity				83.40%
Sempra Infrastructure | Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Debt Instrument [Line Items]
Maximum borrowing capacity				$ 1,600,000,000
Sempra Infrastructure | Other Long-Term Debt, Variable Rate Loan Due December 2025
Debt Instrument [Line Items]
Debt outstanding					$ 455,000,000			$ 341,000,000

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DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2022 MWh MMBTU	Dec. 31, 2021 MWh MMBTU
Natural gas | Long
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU		184
Natural gas | Short
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	193
Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	0	1
Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	49	45
SDG&E | Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	10	7
SDG&E | Electricity
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	0	1
SDG&E | Congestion revenue rights
Derivative [Line Items]
Derivative, nonmonetary notional amount | MWh	49	45
SoCalGas | Natural gas
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	141	201

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DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Interest rate and foreign exchange instruments
Derivative [Line Items]
Notional amount of derivative	$ 306	$ 306
Foreign Exchange Instruments
Derivative [Line Items]
Notional amount of derivative	65	106
Cash Flow Hedging | Interest Rate Contract
Derivative [Line Items]
Notional amount of derivative	$ 436	$ 462

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DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 44	$ 74
Additional cash collateral for commodity contracts not subject to rate recovery	76	58
Additional cash collateral for commodity contracts subject to rate recovery	48	46
Total	168	178
Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	111	62
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	111	62
Other Current Liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(153)	(87)
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	(153)	(87)
Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(58)	(134)
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	(58)	(134)
Derivatives designated as hedging instruments | Other current assets
Derivatives designated as hedging instruments:
Interest rate instruments	5	0
Foreign exchange instruments	0	1
Interest rate and foreign exchange instruments	0	0
Derivatives designated as hedging instruments | Other long-term assets
Derivatives designated as hedging instruments:
Interest rate instruments	27	6
Foreign exchange instruments	0	1
Interest rate and foreign exchange instruments	0	0
Derivatives designated as hedging instruments | Other Current Liabilities
Derivatives designated as hedging instruments:
Interest rate instruments	0	(6)
Foreign exchange instruments	(2)	(1)
Interest rate and foreign exchange instruments	(117)	(1)
Derivatives designated as hedging instruments | Deferred credits and other
Derivatives designated as hedging instruments:
Interest rate instruments	0	(2)
Foreign exchange instruments	0	0
Interest rate and foreign exchange instruments	0	(130)
Derivatives not designated as hedging instruments | Other current assets
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	182	136
Associated offsetting commodity contracts	(167)	(93)
Commodity contracts subject to rate recovery	27	38
Associated offsetting commodity contracts	(3)	(8)
Derivatives not designated as hedging instruments | Other long-term assets
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	91	11
Associated offsetting commodity contracts	(32)	(8)
Commodity contracts subject to rate recovery	25	52
Associated offsetting commodity contracts	0	0
Derivatives not designated as hedging instruments | Other Current Liabilities
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(182)	(122)
Associated offsetting commodity contracts	167	93
Commodity contracts subject to rate recovery	(22)	(58)
Associated offsetting commodity contracts	3	8
Derivatives not designated as hedging instruments | Deferred credits and other
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery	(89)	(10)
Associated offsetting commodity contracts	32	8
Commodity contracts subject to rate recovery	(1)	0
Associated offsetting commodity contracts	0	0
San Diego Gas and Electric Company | Other current assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	23	29
Additional cash collateral for commodity contracts subject to rate recovery	36	28
Total	59	57
San Diego Gas and Electric Company | Other long-term assets
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	25	52
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	25	52
San Diego Gas and Electric Company | Other Current Liabilities
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(11)	(15)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(11)	(15)
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	26	34
Associated offsetting commodity contracts	(3)	(5)
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	25	52
Associated offsetting commodity contracts	0	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	(14)	(20)
Associated offsetting commodity contracts	3	5
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	0	0
Associated offsetting commodity contracts	0	0
Southern California Gas Company | Other current assets
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	12	18
Total	13	19
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	(8)	(35)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(8)	(35)
Southern California Gas Company | Deferred credits and other
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(1)	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(1)	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	1	4
Associated offsetting commodity contracts		(3)
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
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	(8)	(38)
Associated offsetting commodity contracts		3
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	$ (1)	0
Associated offsetting commodity contracts		$ 0

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DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	$ 63	$ (18)	$ 161	$ 89
Pretax (loss) gain on derivatives recognized in earnings	(1)	7	5	(23)
Derivatives designated as hedging instruments | Cash Flow Hedging
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	67	(33)	187	76
Pretax gain (loss) reclassified from AOCI into earnings	(12)	(11)	(17)	(40)
Derivatives designated as hedging instruments | Interest Expense | Cash Flow Hedging | Interest Rate Contract
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	13	(6)	35	20
Pretax gain (loss) reclassified from AOCI into earnings	0	1	1	(1)
Derivatives designated as hedging instruments | Interest Expense | Cash Flow Hedging | Interest Rate Contract | Southern California Gas Company
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	0
Pretax gain (loss) reclassified from AOCI into earnings	(1)	0	(1)	0
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	4	7
Pretax gain (loss) reclassified from AOCI into earnings	1	0	1	0
Derivatives designated as hedging instruments | Equity Earnings | Cash Flow Hedging | Interest Rate Contract
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	50	(32)	144	51
Pretax gain (loss) reclassified from AOCI into earnings	(13)	(19)	(27)	(38)
Derivatives designated as hedging instruments | Equity Earnings | Cash Flow Hedging | Foreign Exchange Instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI	0	(1)	(2)	2
Pretax gain (loss) reclassified from AOCI into earnings	0	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	0	(1)	(3)	2
Pretax gain (loss) reclassified from AOCI into earnings	1	0	2	(1)
Derivatives designated as hedging instruments | Other (Expense) Income, Net | Cash Flow Hedging | Foreign Exchange Instruments
Derivative [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings	(1)	0	(1)	0
Derivatives designated as hedging instruments | Other (Expense) Income, Net | Cash Flow Hedging | Interest rate and foreign exchange instruments
Derivative [Line Items]
Pretax gain (loss) recognized in OCI			13	1
Pretax gain (loss) reclassified from AOCI into earnings	0	7	6	1
Derivatives not designated as hedging instruments
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(179)	(101)	(238)	(169)
Derivatives not designated as hedging instruments | Foreign Exchange Instruments
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	0	0	0	(24)
Derivatives not designated as hedging instruments | Commodity contracts not subject to rate recovery
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(151)	(142)	(228)	(190)
Derivatives not designated as hedging instruments | Commodity contracts subject to rate recovery | Southern California Gas Company
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(4)	0	(4)	2
Derivatives not designated as hedging instruments | Commodity contracts subject to rate recovery | San Diego Gas and Electric Company
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(24)	41	(6)	43
Derivatives not designated as hedging instruments | Cost of Electric Fuel and Purchased Power | Commodity contracts subject to rate recovery
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(24)	41	(6)	43
Derivatives not designated as hedging instruments | Cost of Natural Gas | Commodity contracts subject to rate recovery
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	$ (4)	$ 0	$ (4)	$ 2

XML

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ 6
Cash flow hedge gain (loss) to be reclassified, NCI	$ 11
Term of interest rate cash flow hedge	12 years
Southern California Gas Company
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee
Derivative [Line Items]
Term of interest rate cash flow hedge	17 years

XML

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative fair value	$ 17	$ 88
Collateral	17
Southern California Gas Company
Derivative [Line Items]
Derivative fair value	9	$ 36
Collateral	$ 9

XML

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 876	$ 1,004
Short-term investments held in Rabbi Trust	50	81
Support Agreement, net of related guarantee fees	16	7
Total	1,221	1,332
Total	211	221
Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	15	3
Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	288	364
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	56
Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	293	321
Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	237	260
Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	573	637
Interest Rate Contract
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	32	6
Derivative liabilities		8
Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	74	46
Effect of netting and allocation of collateral	76	58
Derivative liabilities	72	31
Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	49	82
Effect of netting and allocation of collateral	48	46
Derivative liabilities	20	50
Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2
Derivative liabilities	2	1
Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	117	131
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	328	419
Short-term investments held in Rabbi Trust	50	81
Support Agreement, net of related guarantee fees	0	0
Total	499	601
Total	0	0
Level 1 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	15	13
Level 1 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	283	358
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	30	48
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	30	48
Level 1 | Interest Rate Contract
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities		0
Level 1 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	76	58
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	13	12
Effect of netting and allocation of collateral	32	31
Derivative liabilities	0	0
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	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	548	585
Short-term investments held in Rabbi Trust	0	0
Support Agreement, net of related guarantee fees	0	0
Total	665	649
Total	209	206
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	0	(10)
Level 2 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	5	6
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	13	8
Level 2 | Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	293	321
Level 2 | Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	237	260
Level 2 | Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	543	589
Level 2 | Interest Rate Contract
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	32	6
Derivative liabilities		8
Level 2 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	74	46
Effect of netting and allocation of collateral	0	0
Derivative liabilities	72	31
Level 2 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	1
Effect of netting and allocation of collateral	10	9
Derivative liabilities	18	35
Level 2 | Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		2
Derivative liabilities	2	1
Level 2 | Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	117	131
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	16	7
Total	57	82
Total	2	15
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 Contract
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities		0
Level 3 | Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	0
Level 3 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	35	69
Effect of netting and allocation of collateral	6	6
Derivative liabilities	2	15
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	0
San Diego Gas and Electric Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	876	1,004
Total	960	1,113
Total	11	15
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	15	3
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	288	364
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	56
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	293	321
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	237	260
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	573	637
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	48	81
Effect of netting and allocation of collateral	36	28
Derivative liabilities	11	15
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	328	419
Total	371	453
Total	0	0
San Diego Gas and Electric Company | Level 1 | Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	15	13
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	283	358
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	30	48
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	30	48
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	13	12
Effect of netting and allocation of collateral	30	22
Derivative liabilities	0	0
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	548	585
Total	548	585
Total	9	0
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	0	(10)
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	5	6
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	13	8
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	293	321
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	237	260
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	543	589
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	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	9	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	41	75
Total	2	15
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	35	69
Effect of netting and allocation of collateral	6	6
Derivative liabilities	2	15
Southern California Gas Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	13	19
Total	9	35
Southern California Gas Company | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	1
Effect of netting and allocation of collateral	12	18
Derivative liabilities	9	35
Southern California Gas Company | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	2	9
Total	0	0
Southern California Gas Company | Level 1 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	2	9
Derivative liabilities	0	0
Southern California Gas Company | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	11	10
Total	9	35
Southern California Gas Company | Level 2 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	1
Effect of netting and allocation of collateral	10	9
Derivative liabilities	9	35
Southern California Gas Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	0
Total	0	0
Southern California Gas Company | Level 3 | Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Effect of netting and allocation of collateral	0	0
Derivative liabilities	$ 0	$ 0

XML

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022 USD ($) $ / MWh	Jun. 30, 2021 USD ($) $ / MWh	Jun. 30, 2022 USD ($) $ / MWh	Jun. 30, 2021 USD ($) $ / MWh
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 58	$ 62	$ 54	$ 69
Realized and unrealized (losses) gains	(30)	8	(23)	6
Allocated transmission instruments	(6)	(2)	(6)	(2)
Settlements	11	12	8	7
Ending balance	33	80	33	80
Change in unrealized (losses) gains relating to instruments still held at June 30	(23)	14	(18)	12
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	12	3	7	3
Realized and unrealized gains	6	3	14	5
Settlements	(2)	(2)	(5)	(4)
Ending balance	16	4	16	4
Change in unrealized gains (losses) relating to instruments still held at the end of the period	5	2	13	4
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	9		9
San Diego Gas and Electric Company
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	58	62	54	69
Realized and unrealized (losses) gains	(30)	8	(23)	6
Allocated transmission instruments	(6)	(2)	(6)	(2)
Settlements	11	12	8	7
Ending balance	33	80	33	80
Change in unrealized (losses) gains relating to instruments still held at June 30	$ (23)	$ 14	$ (18)	$ 12
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			(3.67)	(1.81)
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	25.25	22.45	25.25	22.45
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			6.96	14.11
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	125.00	151.90	125.00	151.90
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			(0.70)	(0.12)
Market electricity forward price inputs ( in dollars per MWH) | $ / MWh	66.36	49.27	66.36	49.27

XML

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates, allowance for credit losses		$ 1
Allowance for credit losses	$ 7	8
Unamortized transaction costs	5	5
Unamortized discount and debt issuance costs	294	260
Finance lease obligations	1,334	1,335
Due from Unconsolidated Affiliates - Current
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest Receivable	1	2
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term and long-term amounts due from unconsolidated affiliates	626	640
Long-term notes receivable	310	300
Long-term amounts due to unconsolidated affiliate	282	287
Total long-term debt	23,924	20,099
Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term and long-term amounts due from unconsolidated affiliates	630	642
Long-term notes receivable	278	327
Long-term amounts due to unconsolidated affiliate	251	295
Total long-term debt	21,709	22,126
Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term and long-term amounts due from unconsolidated affiliates	0	0
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	0	0
Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term and long-term amounts due from unconsolidated affiliates	630	642
Long-term notes receivable	0	0
Long-term amounts due to unconsolidated affiliate	251	295
Total long-term debt	21,709	22,126
Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term and long-term amounts due from unconsolidated affiliates	0	0
Long-term notes receivable	278	327
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	0	0
San Diego Gas and Electric Company
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount and debt issuance costs	73	61
Finance lease obligations	1,266	1,274
San Diego Gas and Electric Company | Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,800	6,417
San Diego Gas and Electric Company | Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,102	7,236
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	7,102	7,236
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	43	36
Finance lease obligations	68	61
Southern California Gas Company | Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,459	4,759
Southern California Gas Company | Fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,110	5,367
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	5,110	5,367
Southern California Gas Company | Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 0	$ 0

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SAN ONOFRE NUCLEAR GENERATING STATION (Details) - San Diego Gas and Electric Company - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Jointly Owned Nuclear Power Plant [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share (as a percent)	20.00%
Anticipated term of dismantlement work	10 years
Percent of dismantlement work expense (as a percent)	20.00%
ARO related to decommissioning costs	$ 557
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 78

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SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Cost	$ 715		$ 715		$ 735
Gross unrealized gains	190		190		282
Gross unrealized losses	(42)		(42)		(5)
Estimated fair value	863		863		1,012
Proceeds from sales	155	$ 254	397	$ 542
Gross realized gains	3	18	14	39
Gross realized losses	(7)	$ (1)	(11)	$ (3)
Total debt securities
Debt Securities, Available-for-sale [Line Items]
Cost	604		604		620
Gross unrealized gains	3		3		20
Gross unrealized losses	(34)		(34)		(3)
Estimated fair value	573		573		637
U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	43		43		56
Gross unrealized gains	1		1		0
Gross unrealized losses	(1)		(1)		0
Estimated fair value	43		43		56
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	305		305		309
Gross unrealized gains	1		1		13
Gross unrealized losses	(13)		(13)		(1)
Estimated fair value	293		293		321
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	256		256		255
Gross unrealized gains	1		1		7
Gross unrealized losses	(20)		(20)		(2)
Estimated fair value	237		237		260
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	109		109		104
Gross unrealized gains	187		187		262
Gross unrealized losses	(8)		(8)		(2)
Estimated fair value	288		288		364
Short-term investments, primarily cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	15		15		3
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	15		15		3
Receivables (payables), net
Debt Securities, Available-for-sale [Line Items]
Cost	(13)		(13)		8
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ (13)		$ (13)		$ 8

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SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company $ in Millions	Jun. 30, 2022 USD ($)
Schedule Of Nuclear Insurance [Line Items]
Nuclear property damage insurance	$ 130.0
Federal nuclear property damage insurance, minimum required	50.0
Maximum premium assessment under nuclear property damage insurance	$ 4.1

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COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Millions			1 Months Ended	3 Months Ended		4 Months Ended	6 Months Ended
	Aug. 30, 2022 USD ($)	Aug. 01, 2022 plaintiff lawsuit	Jun. 30, 2019 violation	Jun. 30, 2022 USD ($) lawsuit	Jun. 30, 2021 USD ($)	Jan. 31, 2019 plaintiff	Jun. 30, 2022 USD ($) lawsuit	Jun. 30, 2021 USD ($)	Sep. 30, 2021 USD ($)	Jan. 31, 2021 lawsuit
Loss Contingencies [Line Items]
Liability for legal proceedings				$ 2,118			$ 2,118
Number of alleged violations | violation			324
Aliso Canyon litigation and regulatory matters				45	$ 0		137	$ 0
Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings					2,004			2,004
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Liability for legal proceedings				13			13
Southern California Gas Company
Loss Contingencies [Line Items]
Liability for legal proceedings				2,029			2,029
Insurance settlements receivable				1,279			1,279
Aliso Canyon litigation and regulatory matters				45	0		137	0
Southern California Gas Company | Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Liability for legal proceedings					$ 2,004			$ 2,004
Estimate of costs				3,361			3,361
Net book value of Aliso Canyon facility				908			908
Reserve for Aliso Canyon costs				2,003			2,003
Aliso Canyon litigation and regulatory matters				45			137
Aliso Canyon litigation and regulatory matters, net of tax				32			98
Receivable related to natural gas leak				$ 344			344
Insurance proceeds							$ 935
Southern California Gas Company | Shareholder Derivative Complaint
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit				4			4			3
Southern California Gas Company | Complaints Filed by Firefighters | Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff						51
Southern California Gas Company | Individual Plaintiff Litigation | Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Percentage of plaintiffs represented									80.00%
Estimate of costs									$ 1,800
Acceptance rate of plaintiffs (as a percent)									97.00%
Southern California Gas Company | Individual Plaintiff Litigation | Aliso Canyon Natural Gas Storage Facility Gas Leak | Forecast
Loss Contingencies [Line Items]
Expected payment for loss	$ 1,800
Southern California Gas Company | Property Class Action | Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Estimate of costs									$ 40
Sempra Infrastructure | Guaymas-El Oro Segment, Sonora Pipeline
Loss Contingencies [Line Items]
Net book value of pipeline				$ 426			$ 426
Sempra Infrastructure | Regulatory Actions by the Mexican Government
Loss Contingencies [Line Items]
Other intangible assets, net				14			14
Subsequent Event | Southern California Gas Company | Aliso Canyon Natural Gas Storage Facility Gas Leak
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit		390
Number of plaintiffs | plaintiff		36,000
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				$ 4			$ 4

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COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) claim in Thousands, £ in Millions, $ in Millions	1 Months Ended		3 Months Ended	6 Months Ended
	Oct. 31, 2020 GBP (£)	Mar. 31, 2020 GBP (£)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Aug. 01, 2022 lawsuit claim
R B S Sempra Commodities
Loss Contingencies [Line Items]
Equity losses on investment | $			$ 50
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					1
Number of proof of claims | claim					28

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COMMITMENTS AND CONTINGENCIES - LEASE INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Lessee, Lease, Description [Line Items]
Interest income	$ 2	$ 0	$ 4	$ 0
Total revenues from sales-type leases	2	0	4	0
Fixed lease payments	70	59	140	112
Variable lease payments	3	1	4	1
Total revenues from operating leases	73	60	144	113
Depreciation expense	$ 14	$ 12	27	$ 22
San Diego Gas and Electric Company
Lessee, Lease, Description [Line Items]
Lease not yet commenced, remainder of year			7
Lease not yet commenced, year one			18
Lease not yet commenced, year two			18
Lease not yet commenced, year three			18
Lease not yet commenced, year four			18
Lease not yet commenced, thereafter			101
Southern California Gas Company
Lessee, Lease, Description [Line Items]
Finance lease not yet commenced, year one			2
Finance lease not yet commenced, year two			2
Finance lease not yet commenced, year three			2
Finance lease not yet commenced, year four			2
Finance lease not yet commenced, year thereafter			$ 10

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COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 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	$ 59
San Diego Gas and Electric Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	18
Southern California Gas Company
Loss Contingencies [Line Items]
Environmental cost, potential monetary sanctions threshold, actual amount	15
Sempra Infrastructure | Liquefied Natural Gas Contracts
Loss Contingencies [Line Items]
Change in 2022	(208)
Change in 2023	227
Change in 2024	203
Change in 2025	191
Change in 2026	175
Change thereafter	$ 421

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SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($) segment	Jun. 30, 2021 USD ($)	Jun. 01, 2022	Dec. 31, 2021 USD ($)		May 31, 2021	Apr. 30, 2021
Segment Reporting Information [Line Items]
Number of reportable segments | segment			4
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 3,547	$ 2,741	$ 7,367	$ 6,000
DEPRECIATION AND AMORTIZATION	501	463	994	905
INTEREST INCOME	15	15	40	34
INTEREST EXPENSE	271	258	514	517
INCOME TAX EXPENSE (BENEFIT)	80	139	414	297
Equity earnings, before income tax:	159	185	302	320
Equity earnings (losses), net of income tax:	216	128	399	311
Equity earnings	375	313	701	631
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	559	424	1,171	1,298
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			2,361	2,424
ASSETS	75,582		75,582			$ 72,045	[1]
EQUITY METHOD AND OTHER INVESTMENTS	15,093		15,093			14,472
Operating Segments | SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,399	1,318	2,844	2,655
DEPRECIATION AND AMORTIZATION	244	220	483	433
INTEREST INCOME	1	0	1	1
INTEREST EXPENSE	114	101	220	203
INCOME TAX EXPENSE (BENEFIT)	42	33	106	78
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	176	186	410	398
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			1,090	1,072
ASSETS	25,075		25,075			24,058
Operating Segments | SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,501	1,124	3,494	2,632
DEPRECIATION AND AMORTIZATION	188	180	375	353
INTEREST INCOME	1	0	1	0
INTEREST EXPENSE	45	40	85	79
INCOME TAX EXPENSE (BENEFIT)	19	8	103	102
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	87	94	421	501
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			931	936
ASSETS	21,354		21,354			20,324
Operating Segments | Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	689	341	1,113	790
DEPRECIATION AND AMORTIZATION	67	59	132	113
INTEREST INCOME	9	20	30	41
INTEREST EXPENSE	32	45	59	86
INCOME TAX EXPENSE (BENEFIT)	70	94	161	151
Equity earnings, before income tax:	156	133	297	267
Equity earnings (losses), net of income tax:	32	(9)	53	38
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	183	53	278	255
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			336	415
ASSETS	14,958		14,958			14,408
EQUITY METHOD AND OTHER INVESTMENTS	1,687		1,687			1,425
Operating Segments | Sempra Texas Utilities
Segment Reporting Information, Profit (Loss) [Abstract]
Equity earnings, before income tax:	3	2	5	3
Equity earnings (losses), net of income tax:	184	137	346	273
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	186	138	348	273
Segment Reporting Information, Additional Information [Abstract]
ASSETS	13,406		13,406			13,047
EQUITY METHOD AND OTHER INVESTMENTS	13,406		13,406			13,047
All other
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0	1	0	2
DEPRECIATION AND AMORTIZATION	2	4	4	6
INTEREST INCOME	4	1	8	1
INTEREST EXPENSE	81	79	151	162
INCOME TAX EXPENSE (BENEFIT)	(51)	4	44	(34)
Equity earnings, before income tax:	0	50	0	50
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(73)	(47)	(286)	(129)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			4	1
ASSETS	1,984		1,984			1,399
Adjustments and eliminations
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(2)	(1)	0	(1)
Intercompany eliminations
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(40)	(42)	(84)	(78)
INTEREST INCOME	0	(6)	0	(9)
INTEREST EXPENSE	(1)	(7)	(1)	(13)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,195)		(1,195)			$ (1,191)
Intercompany eliminations | SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(3)	(2)	(7)	(4)
Intercompany eliminations | SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(23)	(23)	(49)	(48)
Intercompany eliminations | Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ (14)	$ (17)	$ (28)	$ (26)
Oncor Electric Delivery Company LLC Additional Acquisition | Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest	80.25%		80.25%
Sharyland Holdings, LP | Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest	50.00%		50.00%
SI Partners | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	70.00%		70.00%
Sempra LNG Holding, LP | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	100.00%		100.00%
IEnova
Segment Reporting Information [Line Items]
Ownership interest (as a percent)					99.90%			96.40%	70.20%
IEnova | Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	99.90%		99.90%

[1] Derived from audited financial statements.